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 June 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 July 21, 2015, the issuer had 236,573,788 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	26
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	41
Item 4.	Controls and Procedures	41
Part II. Other Information
Item 1.	Legal Proceedings	42
Item 1A.	Risk Factors	42
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	42
Item 5.	Other Information	42
Item 6.	Exhibits	43
	Signatures	46

i

DEFINITIONS

As commonly used in the liquefied natural gas industry, to the extent applicable, and as used in this quarterly report, the following terms 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 June 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)

	June 30,			December 31,
	2015			2014
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	1,470,207		$	1,747,583
Restricted cash	684,073			481,737
Accounts and interest receivable	6,746			4,419
LNG inventory	13,954			4,294
Other current assets	88,382			20,844
Total current assets	2,263,362			2,258,877
Non-current restricted cash	739,145			550,811
Property, plant and equipment, net	13,799,113			9,246,753
Debt issuance costs, net	637,301			242,323
Non-current derivative assets	21,363			11,744
Goodwill	76,819			76,819
Other non-current assets	222,399			186,356
Total assets	$	17,759,502		$	12,573,683
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	23,799		$	13,426
Accrued liabilities	565,832			169,129
Deferred revenue	26,671			26,655
Derivative liabilities	23,937			23,247
Other current liabilities	600			18
Total current liabilities	640,839			232,475
Long-term debt, net	14,854,794			9,806,084
Non-current deferred revenue	11,500			13,500
Other non-current liabilities	37,013			20,107
Commitments and contingencies (see Footnote 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 June 30, 2015 and December 31, 2014
Issued and outstanding: 236.6 million shares and 236.7 million shares at June 30, 2015 and December 31, 2014, respectively	711			712
Treasury stock: 10.7 million shares and 10.6 million shares at June 30, 2015 and December 31, 2014, respectively, at cost	(298,926		)	(292,752		)
Additional paid-in-capital	3,014,483			2,776,702
Accumulated deficit	(3,035,043		)	(2,648,839		)
Total stockholders’ deficit	(318,775		)	(164,177		)
Non-controlling interest	2,534,131			2,665,694
Total equity	2,215,356			2,501,517
Total liabilities and equity	$	17,759,502		$	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						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Revenues
LNG terminal revenues	$	67,905		$	66,841		$	135,486		$	133,260
Marketing and trading revenues (losses)	(706		)	324			(44		)	981
Other	826			480			952			954
Total revenues	68,025			67,645			136,394			135,195
Operating costs and expenses
General and administrative expense	107,856			67,720			165,873			141,528
Operating and maintenance expense	18,877			29,409			56,030			43,096
Depreciation expense	20,154			17,298			37,923			32,773
Development expense	16,609			15,263			32,705			27,375
Other	109			90			441			170
Total operating costs and expenses	163,605			129,780			292,972			244,942
Loss from operations	(95,580		)	(62,135		)	(156,578		)	(109,747		)
Other income (expense)
Interest expense, net	(85,486		)	(43,789		)	(145,098		)	(84,059		)
Loss on early extinguishment of debt	(7,281		)	(114,335		)	(96,273		)	(114,335		)
Derivative gain (loss), net	45,755			(60,178		)	(80,181		)	(94,859		)
Other income (expense)	283			(189		)	655			121
Total other expense	(46,729		)	(218,491		)	(320,897		)	(293,132		)
Loss before income taxes and non-controlling interest	(142,309		)	(280,626		)	(477,475		)	(402,879		)
Income tax benefit (provision)	507			(84		)	(171		)	(176		)
Net loss	(141,802		)	(280,710		)	(477,646		)	(403,055		)
Less: net loss attributable to non-controlling interest	(23,307		)	(78,782		)	(91,442		)	(103,317		)
Net loss attributable to common stockholders	$	(118,495	)	$	(201,928	)	$	(386,204	)	$	(299,738	)
Net loss per share attributable to common stockholders—basic and diluted	$	(0.52	)	$	(0.90	)	$	(1.71	)	$	(1.34	)
Weighted average number of common shares outstanding—basic and diluted	226,481			223,602			226,405			223,406

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	57		—			—	—			1,914		—			—			1,914
Issuances of restricted stock	16		—			—	—			—		—			—			—
Forfeitures of restricted stock	(138	)	(1		)	14	—			1		—			—			—
Share-based compensation	—		—			—	—			37,411		—			—			37,411
Shares repurchased related to share-based compensation	(80	)	—			80	(6,174		)	—		—			—			(6,174		)
Excess tax benefit from share-based compensation	—		—			—	—			129		—			—			129
Equity portion of issuance of convertible notes, net	—		—			—	—			198,326		—			—			198,326
Loss attributable to non-controlling interest	—		—			—	—			—		—			(91,442		)	(91,442		)
Distributions to non-controlling interest	—		—			—	—			—		—			(40,121		)	(40,121		)
Net loss	—		—			—	—			—		(386,204		)	—			(386,204		)
Balance at June 30, 2015	236,600		$	711		10,690	$	(298,926	)	$	3,014,483	$	(3,035,043	)	$	2,534,131		$	2,215,356

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)

	Six Months Ended
	June 30,
	2015			2014
Cash flows from operating activities
Net loss	$	(477,646	)	$	(403,055	)
Adjustments to reconcile net loss to net cash used in operating activities:
Loss on early extinguishment of debt	96,273			114,335
Depreciation expense	37,923			32,773
Amortization of debt issuance costs and discount	24,900			5,639
Share-based compensation	66,378			62,013
Non-cash LNG inventory write-downs	17,366			14,978
Total losses on derivatives, net	80,198			94,859
Net cash used for settlement of derivative instruments	(88,934		)	(17,437		)
Other	29,133			(1,826		)
Changes in restricted cash for certain operating activities	(55,410		)	82,927
Changes in operating assets and liabilities:
Accounts and interest receivable	(2,396		)	461
Accounts payable and accrued liabilities	42,101			22,856
LNG inventory	(27,026		)	(14,376		)
Deferred revenue	(1,985		)	(1,955		)
Other, net	(35,830		)	(3,533		)
Net cash used in operating activities	(294,955		)	(11,341		)
Cash flows from investing activities
Property, plant and equipment, net	(4,294,814		)	(1,352,400		)
Use of restricted cash for the acquisition of property, plant and equipment	4,183,620			1,303,011
Other	(101,836		)	(5,894		)
Net cash used in investing activities	(213,030		)	(55,283		)
Cash flows from financing activities
Proceeds from issuances of long-term debt	5,205,000			2,584,500
Investment in restricted cash	(4,518,880		)	(2,282,903		)
Debt issuance and deferred financing costs	(411,149		)	(85,367		)
Distributions and dividends to non-controlling interest	(40,121		)	(39,644		)
Repayments of long-term debt	—			(177,000		)
Payments related to tax withholdings for share-based compensation	(6,174		)	(9,218		)
Proceeds from exercise of stock options	1,914			6,265
Other	19			(964		)
Net cash provided by (used in) financing activities	230,609			(4,331		)
Net decrease in cash and cash equivalents	(277,376		)	(70,955		)
Cash and cash equivalents—beginning of period	1,747,583			960,842
Cash and cash equivalents—end of period	$	1,470,207		$	889,887

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 six months ended June 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 both June 30, 2015 and December 31, 2014, we classified $15.0 million as current restricted cash for the payment of current interest due. As of both June 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, 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 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 (the “Additional 2023 SPL Senior Notes” and collectively with the Initial 2023 SPL Senior Notes, the “2023 SPL Senior Notes”) in an aggregate principal amount of $0.5 billion, before premium. 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

7

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 June 30, 2015 and December 31, 2014, we classified $340.5 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 $656.0 million 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 June 30, 2015 and December 31, 2014, we classified $19.0 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 such funds may only be used for modifications of the 94-mile Creole Trail Pipeline, which interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines, 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”), which 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, and the Corpus Christi Pipeline, 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”) and approximately $3.1 billion linked to the second stage (“Stage 2”) of the CCL Project, which 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 June 30, 2015, we classified $92.0 million and zero as current restricted cash and non-current restricted cash, respectively, held by CCH.

Other Restricted Cash

As of June 30, 2015 and December 31, 2014, $196.0 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 June 30, 2015 and December 31, 2014, $21.6 million and $35.9 million, respectively, had been classified as current restricted cash, and as of June 30, 2015 and December 31, 2014, $7.0 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):

	June 30,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	2,466,559		$	2,269,429
LNG terminal construction-in-process	11,495,832			7,155,046
LNG site and related costs, net	9,391			9,395
Accumulated depreciation	(381,285		)	(350,497		)
Total LNG terminal costs, net	13,590,497			9,083,373
Fixed assets and other
Computer and office equipment	10,145			7,464
Furniture and fixtures	16,620			10,733
Computer software	64,320			46,882
Leasehold improvements	38,047			36,067
Land	59,087			55,522
Other	53,624			36,881
Accumulated depreciation	(33,227		)	(30,169		)
Total fixed assets and other, net	208,616			163,380
Property, plant and equipment, net	$	13,799,113		$	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”);

• 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”); 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”).

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 June 30, 2015 and December 31, 2014, which are classified as other current assets, non-current derivative assets, derivative liabilities and other non-current liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	June 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 (liability)	$	—	$	(315	)	$	—	$	(315	)	$	—	$	219		$	—	$	219
Liquefaction Supply Derivatives asset (liability)	—		(27		)	440		413			—		—			342		342
SPL Interest Rate Derivatives liability	—		(8,172		)	—		(8,172		)	—		(12,036		)	—		(12,036		)
CCH Interest Rate Derivatives asset	—		5,335			—		5,335			—		—			—		—

The estimated fair values of our Natural Gas Derivatives and the economic hedges related to the Liquefaction Supply 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 our 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, 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 June 30, 2015 and December 31, 2014, the majority of the Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow. Therefore, our internal fair value models were based on a market price that equated 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.

There were no transfers into or out of Level 3 Liquefaction Supply Derivatives for the three and six months ended June 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 (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of June 30, 2015:

	Net Fair Value Asset	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Liquefaction Supply Derivatives	$440	Income Approach	Basis Spread	$ (0.350) - $0.020

10

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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.  

Commodity Derivatives

We recognize all commodity derivative instruments, including our Natural Gas Derivatives and the Liquefaction Supply 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:

	June 30, 2015									December 31, 2014
	Natural Gas Derivatives (1)			Liquefaction Supply Derivatives			Total			Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			Total
Balance Sheet Location
Other current assets	$	181		$	307		$	488		$	219	$	76		$	295
Non-current derivative assets	—			426			426			—		586			586
Total derivative assets	181			733			914			219		662			881
Derivative liabilities	(496		)	(222		)	(718		)	—		(53		)	(53		)
Other non-current liabilities	—			(98		)	(98		)	—		(267		)	(267		)
Total derivative liabilities	(496		)	(320		)	(816		)	—		(320		)	(320		)
Derivative asset (liability), net	$	(315	)	$	413		$	98		$	219	$	342		$	561

(1) Does not include collateral of $6.3 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of June 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 six months ended June 30, 2015 and 2014:

		Three Months Ended June 30,						Six Months Ended June 30,
	Statement of Operations Location	2015			2014			2015			2014
Natural Gas Derivatives gain (loss)	Marketing and trading revenues (losses)	$	67		$	21		$	(98	)	$	370
Natural Gas Derivatives gain (loss)	Derivative gain (loss), net	(294		)	(56		)	460			(258		)
Natural Gas Derivatives gain	Operating and maintenance expense	—			—			—			44
Liquefaction Supply Derivatives gain (1)	Operating and maintenance expense	81			—			81			—

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

The use of Commodity Derivatives exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our Commodity Derivatives are in an asset position.

11

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 June 30, 2015, SPL has secured up to approximately 2,162.8 million MMBtu 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 1,250.3 million MMBtu, which were recorded as derivatives due to minimum purchase requirements.

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 its interest rate derivatives related to the 2013 SPL Credit Facilities 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 June 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	$690.8 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

12

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table (in thousands) shows the fair value of our interest rate derivatives:

	June 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
Other current assets	$	—		$	—		$	—		$	—		$	—	$	—
Non-current derivative assets	—			20,937			20,937			11,158			—		11,158
Total derivative assets	—			20,937			20,937			11,158			—		11,158
Derivative liabilities	(7,617		)	(15,602		)	(23,219		)	(23,194		)	—		(23,194		)
Other non-current liabilities	(555		)	—			(555		)	—			—		—
Total derivative liabilities	(8,172		)	(15,602		)	(23,774		)	(23,194		)	—		(23,194		)
Derivative asset (liability), net	$	(8,172	)	$	5,335		$	(2,837	)	$	(12,036	)	$	—	$	(12,036	)

The following table (in thousands) shows the changes in the fair value and settlements of our 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 six months ended June 30, 2015 and 2014:

	Three Months Ended June 30,					Six Months Ended June 30,
	2015		2014			2015			2014
SPL Interest Rate Derivatives gain (loss)	$	1,469	$	(60,122	)	$	(35,669	)	$	(94,601	)
CCH Interest Rate Derivatives gain (loss)	44,580		—			(44,972		)	—

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 June 30, 2015
Natural Gas Derivatives	$	(595	)	$	280		$	(315	)
Liquefaction Supply Derivatives	733			—			733
Liquefaction Supply Derivatives	(320		)	—			(320		)
SPL Interest Rate Derivatives	(8,172		)	—			(8,172		)
CCH Interest Rate Derivatives	20,937			—			20,937
CCH Interest Rate Derivatives	(15,602		)	—			(15,602		)
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 June 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

13

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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

	June 30,		December 31,
	2015		2014
Interest expense and related debt fees	$	235,996	$	112,858
Employee-related costs	78,908		6,425
LNG liquefaction costs	229,375		22,014
LNG terminal costs	6,477		1,077
Other accrued liabilities	15,076		26,755
Total accrued liabilities	$	565,832	$	169,129

NOTE 7—LONG-TERM DEBT

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

	Interest	June 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)	—			—
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)	400,000			400,000
2015 CCH Credit Facility (4)	(5)	1,705,000			—
Total long-term debt		15,348,120			9,989,969
Long-term debt premium (discount)
2016 SPLNG Senior Notes		(6,651		)	(8,998		)
2021 SPL Senior Notes		9,457			10,177
2023 SPL Senior Notes		6,745			7,088
2021 Cheniere Convertible Unsecured Notes		(180,862		)	(189,717		)
2045 Cheniere Convertible Senior Notes		(320,083		)	—
CTPL Term Loan		(1,932		)	(2,435		)
Total long-term debt, net		$	14,854,794		$	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) 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.

14

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

(4) 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.

(5) 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.

For the three months ended June 30, 2015 and 2014, we incurred $241.2 million and $140.4 million of total interest cost, respectively, of which we capitalized and deferred $155.7 million and $96.6 million, respectively, of interest cost, including amortization of debt issuance costs, primarily related to the construction of the first four Trains of the SPL Project. For the six months ended June 30, 2015 and 2014, we incurred $421.9 million and $269.0 million of total interest cost, respectively, of which we capitalized and deferred $276.8 million and $184.9 million, respectively, of interest cost, 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 six months ended June 30, 2015 and 2014, SPLNG made distributions of $199.6 million and $173.0 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 periods.

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 June 30, 2015, SPL had $4.6 billion of available commitments and no outstanding borrowings under the 2015 SPL Credit Facilities.

SPL incurred $89.9 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 either: (1) a rate per annum equal to 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.

15

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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.

Under the terms of the 2015 SPL Credit Facilities, within 90 days of the closing date, 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 $7.3 million and $96.3 million for the three and six months ended June 30, 2015, respectively.

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 June 30, 2015 and December 31, 2014, the carrying value of the equity component was $195.7 million and $191.5 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 June 30, 2015 and December 31, 2014, respectively, and the remaining period over which the debt discount will be amortized was 5.9 years as of June 30, 2015. As of June 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

16

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 Convertible 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 Cheniere CCH HoldCo I.

At our 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 our 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 June 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 June 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 June 30, 2015, and the remaining period over which the debt discount will be amortized was 29.7 years. As of June 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 June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Interest per contractual rate	$	33,603	$	—	$	47,542	$	—
Amortization of debt discount	7,116		—		13,714		—
Amortization of debt issuance costs	601		—		615		—
Total interest expense related to the Convertible Notes	$	41,320	$	—	$	61,871	$	—

17

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

CTPL Term Loan

As of June 30, 2015, CTPL had borrowed the full amount of $400.0 million available under the CTPL Term Loan. The CTPL Term Loan matures in 2017 when the full amount of the outstanding principal obligations must be repaid.  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 June 30, 2015, CCH had $6.7 billion of available commitments and $1.7 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 1.55x.

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, within 90 days of the closing date, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt.

SPL LC Agreement

In April 2014, SPL entered into a $325.0 million senior letter of credit and reimbursement agreement (the “SPL LC Agreement”) that it uses for the issuance of letters of credit for certain working capital requirements related to the SPL Project. SPL pays (1) a commitment fee in an amount equal to an annual rate of 0.75% of an amount equal to the unissued portion of letters of credit available pursuant to the SPL LC Agreement and (2) a letter of credit fee equal to an annual rate of 2.5% of the undrawn portion of all letters of credit issued under the SPL LC Agreement. If draws are made upon any letters of credit issued under the SPL LC Agreement, the amount of the draw will be deemed a loan issued to SPL.  SPL is required to pay the full amount of this loan on or prior to the business day immediately succeeding the deemed issuance of the loan.  These loans accrue interest at a rate of 2.0% plus the base rate as defined in the SPL LC Agreement. As of June 30, 2015 and December 31, 2014, SPL had issued letters of credit in an aggregate amount of $72.9 million and $9.5 million, respectively, and as of both June 30, 2015 and December 31, 2014, no draws had been made upon any letters of credit issued under the SPL LC Agreement.

18

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Fair Value Disclosures

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

	June 30, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 SPLNG Senior Notes, net of discount (1)	$	1,658,849	$	1,745,939	$	1,656,502	$	1,718,621
2020 SPLNG Senior Notes (1)	420,000		435,750		420,000		428,400
2021 SPL Senior Notes, net of premium (1)	2,009,457		2,049,646		2,010,177		1,985,050
2022 SPL Senior Notes (1)	1,000,000		1,027,500		1,000,000		1,020,000
2023 SPL Senior Notes, net of premium (1)	1,506,745		1,493,561		1,507,089		1,476,947
2024 SPL Senior Notes (1)	2,000,000		1,982,500		2,000,000		1,970,000
2025 SPL Senior Notes (1)	2,000,000		1,960,000		—		—
2015 SPL Credit Facilities (2)	—		—		—		—
2021 Cheniere Convertible Unsecured Notes, net of discount (3)	848,091		1,054,059		814,751		1,025,563
2025 CCH Holdco II Convertible Senior Notes (3)	1,003,667		928,591		—		—
2045 Cheniere Convertible Senior Notes, net of discount (4)	304,917		470,706		—		—
CTPL Term Loan, net of discount (2)	398,068		400,000		397,565		400,000
2015 CCH Credit Facility (2)	1,705,000		1,705,000		—		—

(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 June 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 (expense) of $0.5 million and $(0.1) million for the three months ended June 30, 2015 and 2014, respectively, and a net expense of $0.2 million for each of the six months ended June 30, 2015 and 2014 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.

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”).

19

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 2011 Plan. As of June 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 the Board of Directors approved the 2014-2018 LTIP, which is a sub-plan of the Company’s 2015 Long-Term Cash Incentive Plan. 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 awarded generally 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 issued 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 records 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. During the three and six months ended June 30, 2015, we granted 5.5 million and 5.6 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 six months ended June 30, 2014.

For the three months ended June 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $50.3 million and $26.1 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $18.4 million and $2.5 million, respectively. For the six months ended June 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $66.4 million and $62.0 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $20.3 million and $4.3 million, respectively. We did not recognize any cumulative adjustments in our compensation expense for the six months ended June 30, 2015 and 2014.

The total unrecognized compensation cost at June 30, 2015 relating to non-vested share-based compensation arrangements was $462.2 million, which is expected to be recognized over a weighted average period of 2.5 years.

We received $0.9 million and $2.6 million in the three months ended June 30, 2015 and 2014, respectively, and $1.9 million and $6.3 million in the six months ended June 30, 2015 and 2014, respectively, of proceeds from the exercise of stock options.

During the three and six months ended June 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 six months ended June 30, 2015.

20

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 reconciles basic and diluted weighted average common shares outstanding for the three and six months ended June 30, 2015 and 2014 (in thousands, except for loss per share):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Weighted average common shares outstanding:
Basic	226,481			223,602			226,405			223,406
Dilutive common stock options (1)	—			—			—			—
Diluted	226,481			223,602			226,405			223,406
Basic and diluted net loss per share attributable to common stockholders	$	(0.52	)	$	(0.90	)	$	(1.71	)	$	(1.34	)

(1) Stock options and unvested stock of 10.1 million shares and 14.5 million shares for the three months ended June 30, 2015 and 2014, respectively, and 10.1 million shares and 14.4 million shares for the six months ended June 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, 38.6 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 six months ended June 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 Incentive 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.

21

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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.

22

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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

	Segments
	LNG Terminal			LNG & Natural Gas Marketing			Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended June 30, 2015
Revenues (losses) from external customers (2)	$	68,532		$	(706	)	$	199		$	68,025
Intersegment revenues (losses) (3)	491			6,354			(6,845		)	—
Depreciation expense	16,071			244			3,839			20,154
Loss from operations	(17,767		)	(26,367		)	(51,446		)	(95,580		)
Interest expense, net	(59,465		)	—			(26,021		)	(85,486		)
Loss before income taxes and non-controlling interest (4)	(33,403		)	(26,816		)	(82,090		)	(142,309		)
Share-based compensation	25,778			6,052			36,835			68,665
Goodwill	76,819			—			—			76,819
Total assets	15,964,158			567,541			1,227,803			17,759,502
Expenditures for additions to long-lived assets	3,944,191			1,400			20,874			3,966,465
As of or for the Three Months Ended June 30, 2014
Revenues from external customers (2)	$	66,841		$	324		$	480		$	67,645
Intersegment revenues (losses) (3)	734			1,900			(2,634		)	—
Depreciation expense	14,810			109			2,379			17,298
Loss from operations	(20,607		)	(14,907		)	(26,621		)	(62,135		)
Interest expense, net	(43,895		)	—			106			(43,789		)
Loss before income taxes and non-controlling interest (4)	(234,123		)	(15,189		)	(31,314		)	(280,626		)
Share-based compensation	3,512			2,421			22,686			28,619
Goodwill	76,819			—			—			76,819
Total assets	10,861,606			63,020			934,669			11,859,295
Expenditures for additions to long-lived assets	809,658			471			6,315			816,444
For the Six Months Ended June 30, 2015
Revenues (losses) from external customers (2)	$	136,112		$	(44	)	$	326		$	136,394
Intersegment revenues (losses) (3)	594			13,371			(13,965		)	—
Depreciation expense	31,012			444			6,467			37,923
Loss from operations	(42,856		)	(31,550		)	(82,172		)	(156,578		)
Interest expense, net	(102,310		)	—			(42,788		)	(145,098		)
Loss before income taxes and non-controlling interest (4)	(311,058		)	(32,206		)	(134,211		)	(477,475		)
Share-based compensation	28,917			10,087			47,651			86,655
Expenditures for additions to long-lived assets	4,534,436			2,114			49,655			4,586,205
For the Six Months Ended June 30, 2014
Revenues from external customers (2)	$	133,260		$	982		$	953		$	135,195
Intersegment revenues (losses) (3)	1,506			4,074			(5,580		)	—
Depreciation expense	29,216			261			3,296			32,773
Loss from operations	(28,123		)	(26,501		)	(55,123		)	(109,747		)
Interest expense, net	(84,268		)	—			209			(84,059		)
Loss before income taxes and non-controlling interest (4)	(311,477		)	(26,916		)	(64,486		)	(402,879		)
Share-based compensation	6,562			8,931			50,824			66,317
Expenditures for additions to long-lived assets	1,469,437			785			32,225			1,502,447

(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.

23

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

	Six Months Ended June 30,
	2015		2014
Cash paid during the year for interest, net of amounts capitalized and deferred	$	46,165	$	49,219
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	383,722		286,388

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, 2016, including interim periods within that reporting period, with earlier adoption not 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 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. 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.

24

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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.

25

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,

26

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 the 94-mile Creole Trail Pipeline through a wholly owned subsidiary, CTPL, which interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines.

We are developing and constructing a second natural gas liquefaction and export facility and pipeline facility on over 1,000 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”).

One of our subsidiaries, 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 $495.7 million, after deducting estimated fees and estimated offering expenses of $4.3 million, 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).

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;

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• Cheniere Partners through operating cash flows from SPLNG and SPL, 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 June 30, 2015, we had cash and cash equivalents of $1,470.2 million available to Cheniere. In addition, we had current and non-current restricted cash of $1,423.2 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: $92.0 million for the CCL Project; $996.5 million for the SPL Project; $19.0 million for CTPL; $91.1 million for interest payments related to the SPLNG Senior Notes described below; and $224.6 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 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.

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 June 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 six months ended June 30, 2015, we received $7.2 million in dividends on our Cheniere Holdings common shares and $0.5 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 June 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 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 six months ended June 30, 2015, we received $1.0 million in distributions on our general partner interest and $32.9 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

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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 1.51 and 1.49, respectively, as of June 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.

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 further 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

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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 June 30, 2015, the overall project completion percentages for Trains 1 and 2 and Trains 3 and 4 of the SPL Project were approximately 92.2% and 69.2%, respectively, which are 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 June 30, 2015, SPL has secured up to approximately 2,162.8 million MMBtu 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 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 (Trains 1 and 2)”), EPC contract for Trains 3 and 4 (“EPC Contract (Trains 3 and 4)”) and EPC Contract (Train 5) are approximately $4.1 billion, $3.8 billion and $3.0 billion, respectively, reflecting amounts incurred under change orders through June 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

CTPL owns the Creole Trail Pipeline, a 94-mile pipeline interconnecting the Sabine Pass LNG terminal with a number of large interstate pipelines. In December 2013, CTPL began construction of certain modifications to allow the Creole Trail Pipeline to be able to transport natural gas to the Sabine Pass LNG terminal, which were completed in April 2015.

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Final Investment Decision on Train 6

We will contemplate making an 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 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, when Train 1 of the SPL Project is anticipated to achieve initial LNG production.

Senior Secured Notes

As of June 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

• 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

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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 six months ended June 30, 2015 and 2014, SPLNG made distributions of $199.6 million and $173.0 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 a $325.0 million senior letter of credit and reimbursement agreement (the “SPL LC Agreement”) described below.

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 June 30, 2015, SPL had $4.6 billion of available commitments and no 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 either: (1) a rate per annum equal to 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 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.

Under the terms of the 2015 SPL Credit Facilities, within 90 days of the closing date, 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.

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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 $7.3 million and $96.3 million for the three and six months ended June 30, 2015, respectively.

CTPL Term Loan

CTPL has a $400.0 million term loan facility (“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 June 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 LC Agreement

In April 2014, SPL entered into the SPL LC Agreement that it uses for the issuance of letters of credit for certain working capital requirements related to the SPL Project.  SPL pays (1) a commitment fee in an amount equal to an annual rate of 0.75% of an amount equal to the unissued portion of letters of credit available pursuant to the SPL LC Agreement and (2) a letter of credit fee equal to an annual rate of 2.5% of the undrawn portion of all letters of credit issued under the SPL LC Agreement. If draws are made upon any letters of credit issued under the SPL LC Agreement, the amount of the draw will be deemed a loan issued to SPL.  SPL is required to pay the full amount of this loan on or prior to the business day immediately succeeding the deemed issuance of the loan.  These loans accrue interest at a rate of 2.0% plus the base rate as defined in the SPL LC Agreement. As of June 30, 2015, SPL had issued letters of credit in an aggregate amount of $72.9 million and no draws had been made upon any letters of credit issued under the SPL LC Agreement.

Corpus Christi LNG Terminal

Liquefaction Facilities

The CCL Project is being developed and constructed on over 1,000 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. 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.

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,

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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.

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 pipeline, are approximately $7.5 billion and $2.4 billion, respectively, reflecting amounts incurred under change orders through June 30, 2015. Total expected capital costs for Stages 1 and 2 are estimated to be 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.

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,

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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 Convertible 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 Cheniere CCH HoldCo I.

At our 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 our 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 June 30, 2015, CCH had $6.7 billion of available commitments and $1.7 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 1.55x. 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, within 90 days of the closing date, 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

Our wholly owned subsidiary, 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, or one of its wholly owned subsidiaries, 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;

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• 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

• three LNG vessel time charters with subsidiaries of two ship owners, Dynagas, Ltd. (“Dynagas”) and Teekay LNG Operating LLC (“Teekay”). The annual payments for the vessel charters will be approximately $92 million. The charters have an initial term of 5 years with the option to renew with Dynagas for a 2-year extension with similar terms as the initial term. Cheniere Marketing received the first vessel from Dynagas in June 2015 and expects to receive the remaining two vessels from Teekay in January 2016 and June 2016.

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, a wholly owned subsidiary of Cheniere Marketing has 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 a final investment decision related to certain projects and obtaining related financing.

Corporate and Other Activities

We are required to maintain corporate 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 summarizes (in thousands) the sources and uses of our cash and cash equivalents for the six months ended June 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. 

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	Six Months Ended June 30,
	2015			2014
Sources of cash and cash equivalents
Proceeds from issuances of long-term debt	$	5,205,000		$	2,584,500
Use of restricted cash for the acquisition of property, plant and equipment	4,183,620			1,303,011
Proceeds from exercise of stock options	1,914			6,265
Other	19			—
Total sources of cash and cash equivalents	9,390,553			3,893,776
Uses of cash and cash equivalents
Investment in restricted cash	(4,518,880		)	(2,282,903		)
Property, plant and equipment, net	(4,294,814		)	(1,352,400		)
Debt issuance and deferred financing costs	(411,149		)	(85,367		)
Repayments of long-term debt	—			(177,000		)
Distributions and dividends to non-controlling interest	(40,121		)	(39,644		)
Payments related to tax withholdings for share-based compensation	(6,174		)	(9,218		)
Operating cash flow	(294,955		)	(11,341		)
Other	(101,836		)	(6,858		)
Total uses of cash and cash equivalents	(9,667,929		)	(3,964,731		)
Net decrease in cash and cash equivalents	(277,376		)	(70,955		)
Cash and cash equivalents—beginning of period	1,747,583			960,842
Cash and cash equivalents—end of period	$	1,470,207		$	889,887

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 $1.7 billion under this facility during the second quarter of 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. Debt issuance and deferred financing costs in the six months ended June 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 six months ended June 30, 2014 primarily relate to up-front fees paid upon the closing of this offering in May 2014.

During the six months ended June 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 six months ended June 30, 2015 and 2014, we used $4,183.6 million and $1,303.0 million, respectively, of restricted cash for investing activities to fund $4,294.8 million and a portion of the $1,352.4 million used for the acquisition of property, plant and equipment during the six months ended June 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 six months ended June 30, 2015, we invested $4,518.9 million in restricted cash primarily related to the net proceeds from the 2025 SPL Senior Notes, partially offset by the payment of distributions to non-controlling interest. In the six months

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ended June 30, 2014, we invested $2,282.9 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 six months ended June 30, 2015 and 2014, Cheniere Partners and Cheniere Holdings, collectively, made distributions and paid dividends of $40.1 million and $39.6 million, respectively, to non-affiliated common unitholders and common shareholders.

Payments Related to Tax Withholdings for Share-based Compensation

During the six months ended June 30, 2015 and 2014, we used $6.2 million and $9.2 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 $295.0 million during the six months ended June 30, 2015, compared to a cash outflow of $11.3 million during the six months ended June 30, 2014. This increase in operating cash outflows primarily related to the timing of amounts paid to third parties for the construction of the SPL Project and the CCL Project and fees 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 (the “CCH Interest Rate Derivatives”). These amounts were partially offset by cash paid to purchase LNG to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal and the timing of receivables due from third parties.

Other

Other cash outflows increased from $6.9 million during the six months ended June 30, 2014 to $101.8 million during the six months ended June 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 and investments made in connection with the mid-scale natural gas liquefaction projects being developed with Parallax.

Issuance of Common Stock

 During the six months ended June 30, 2015 and 2014, we issued 16,000 and 0.4 million shares, respectively, of restricted stock to new and existing employees.

Results of Operations

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

Our consolidated net loss attributable to common stockholders was $118.5 million, or $0.52 per share (basic and diluted), in the three months ended June 30, 2015 compared to a net loss attributable to common stockholders of $201.9 million, or $0.90 per share (basic and diluted), in the three months ended June 30, 2014. This $83.4 million decrease in net loss was primarily a result of decreased loss on early extinguishment of debt and increased derivative gain (loss), net, which was partially offset by increased general and administrative expense (“G&A Expense”) and increased interest expense, net.

Loss on early extinguishment of debt decreased $107.1 million in the three months ended June 30, 2015, as compared to the three months ended June 30, 2014, due to the $7.3 million write-off of debt issuance costs and deferred commitment fees in connection with the termination and replacement of the 2013 SPL Credit Facilities with the 2015 SPL Credit Facilities in June 2015, as compared to the $114.3 million write-off of debt issuance costs in connection with the early extinguishment of $2.1 billion of commitments under the 2013 SPL Credit Facilities in May 2014. Derivative gain (loss), net increased $106.0 million from a loss of $60.2 million in the three months ended June 30, 2014 to a gain of $45.8 million in the three months ended June 30, 2015, primarily as a result of an increase in long-term LIBOR during the three months ended June 30, 2015, partially offset by the loss recognized upon meeting the contingency related to the CCH Interest Rate Derivatives, as compared to a decrease in long-term LIBOR during the three months ended June 30, 2014.

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G&A Expense increased $40.1 million in the three months ended June 30, 2015, as compared to the three months ended June 30, 2014, primarily due to increased share-based compensation. Interest expense, net increased $41.7 million in the three months ended June 30, 2015, as compared to the three months ended June 30, 2014, primarily as a result of an increase in our indebtedness outstanding as of June 30, 2015 compared to June 30, 2014. For the three months ended June 30, 2015 and 2014, we incurred $241.2 million and $140.4 million of total interest cost, respectively, of which we capitalized and deferred $155.7 million and $96.6 million, respectively, which were directly related to the construction of the SPL Project.

Six Months EndedJune 30, 2015 vs. Six Months EndedJune 30, 2014

Our consolidated net loss attributable to common stockholders was $386.2 million, or $1.71 per share (basic and diluted), in the six months ended June 30, 2015 compared to a net loss attributable to common stockholders of $299.7 million, or $1.34 per share (basic and diluted), in the six months ended June 30, 2014. This $86.5 million increase in net loss was primarily a result of increased interest expense, net and increased G&A Expense, which was partially offset by decreased loss on early extinguishment of debt and decreased derivative loss, net.

Interest expense, net increased $61.0 million in the six months ended June 30, 2015, as compared to the six months ended June 30, 2014, primarily as a result of an increase in our indebtedness outstanding as of June 30, 2015 compared to June 30, 2014. For the six months ended June 30, 2015 and 2014, we incurred $421.9 million and $269.0 million of total interest cost, respectively, of which we capitalized and deferred $276.8 million and $184.9 million, respectively, which were directly related to the construction of the SPL Project. G&A Expense increased $24.3 million in the six months ended June 30, 2015, as compared to the six months ended June 30, 2014, primarily due to increased professional fees and increased compensation expense as a result of increased headcount.

Loss on early extinguishment of debt decreased $18.1 million in the six months ended June 30, 2015, as compared to the six months ended June 30, 2014, primarily due to $96.3 million of debt issuance costs and deferred commitment fees written off in connection with the termination of approximately $1.8 billion of commitments under the 2013 SPL Credit Facilities in March 2015 and the replacement of the 2013 SPL Credit Facilities with the 2015 SPL Credit Facilities in June 2015, as compared to the $114.3 million write-off of debt issuance costs in connection with the early extinguishment of $2.1 billion of commitments under the 2013 SPL Credit Facilities in May 2014. Derivative loss, net decreased $14.7 million during the six months ended June 30, 2015, as compared to the six months ended June 30, 2014. The derivative loss recognized during the six months ended June 30, 2014 was attributable to a decrease in long-term LIBOR. The derivative loss recognized during the six months ended June 30, 2015 was primarily 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.

Off-Balance Sheet Arrangements

As of June 30, 2015, we had no “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.

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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”); and

• commodity derivatives consisting of natural gas purchase agreements to secure natural gas feedstock for the SPL Project (“Liquefaction Supply 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 June 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 June 30, 2015, we estimated the fair value of the Liquefaction Supply Derivatives to be $0.4 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 $0.4 million as of June 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 full 7-year 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 $3.5 million as of June 30, 2015.

CCH has entered into 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”). 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 full 7-year 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 $58.4 million as of June 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 June 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
April 1 - 30, 2015	19,065	$77.66	—	—
May 1 - 31, 2015	11,525	$77.84	—	—
June 1 - 30, 2015	—	$—	—	—

(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 June 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 June 30, 2015, we did not engage in any transactions with Iran or with persons or entities related to Iran.

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ITEM 6.    EXHIBITS

Exhibit No.	Description
3.1*	Amended and Restated Bylaws of Cheniere Energy, Inc.
4.1	Amendment to Amended and Restated Note Purchase Agreement, dated as of March 16, 2015, by and among Issuer, the Company, EIG Management Company, LLC, as administrative agent and the note purchasers named therein (Incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
4.2	Amendment 2 to Amended and Restated Note Purchase Agreement, dated as of May 8, 2015, with effect as of May 1, 2015, by and among Issuer, the Company, EIG Management Company, LLC, as administrative agent and the note purchasers named therein (Incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
4.3	Form of 11.0% Senior Secured Notes due 2025 (Incorporated by reference to Exhibit 4.4 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.1	Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 3 Liquefaction Facility, dated May 4, 2015, by and between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc. (Portions of this exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment.) (Incorporated by reference to Exhibit 10.1 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K/A (SEC File No. 001-33366), filed on July 1, 2015)
10.2	Common Terms Agreement, dated May 13, 2015, among Cheniere Corpus Christi Holdings, LLC, Cheniere Corpus Christi Pipeline, L.P., Corpus Christi Pipeline GP, LLC, Corpus Christi Liquefaction, LLC, Société Générale as Term Loan Facility Agent and as Intercreditor Agent and any other facility agents party thereto from time (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.3	Common Security and Account Agreement, dated May 13, 2015, among Cheniere Corpus Christi Holdings, LLC, Cheniere Corpus Christi Pipeline, L.P., Corpus Christi Pipeline GP, LLC, Corpus Christi Liquefaction, LLC, the Initial Senior Creditor Group Representatives and Senior Creditor Group Representatives from time to time, for the benefit of all Senior Creditors, Société Générale as the Intercreditor Agent for the Facility Lenders and any Hedging Banks, Société Générale as the Security Trustee and Mizuho Bank, Ltd as the Account Bank (Incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.4	Pledge Agreement, dated May 13, 2015, among Cheniere CCH HoldCo I, LLC and Société Générale as Security Trustee (Incorporated by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.5	Term Loan Facility Agreement, dated May 13, 2015, among Cheniere Corpus Christi Holdings, LLC, Cheniere Corpus Christi Pipeline, L.P., Corpus Christi Pipeline GP, LLC, Corpus Christi Liquefaction, LLC, Term Lenders party thereto from time to time and Société Générale as the Term Loan Facility Agent (Incorporated by reference to Exhibit 10.4 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.6	Equity Contribution Agreement, dated May 13, 2015, among Cheniere Corpus Christi Holdings, LLC, and the Company (Incorporated by reference to Exhibit 10.5 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.7	Registration Rights Agreement, dated May 13, 2015, among the Company, Cheniere CCH HoldCo II, LLC, and EIG Management Company, LLC as Agent on behalf of the Note Holders (Incorporated by reference to Exhibit 10.6 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.8	Pledge Agreement, dated May 13, 2015, among the Company, EIG Management Company, LLC as Agent for the Note Holders, and The Bank of New York Mellon as the Collateral Agent for the Note Holders (Incorporated by reference to Exhibit 10.7 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.9	Pledge Agreement, dated May 13, 2015, among Cheniere CCH HoldCo II, LLC, EIG Management Company, LLC as Agent for the Note Holders, and The Bank of New York Mellon as the Collateral Agent for the Note Holders (Incorporated by reference to Exhibit 10.8 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on May 13, 2015)
10.10	Change order to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Liquefaction Facility, dated as of November 11, 2011, between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: the Change Order CO-00041 Additional Building Utility Tie-in Packages and Fire and Gas Modifications, dated April 9, 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 July 30, 2015)

43

Exhibit No.	Description
10.11	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-00018 Permanent Restroom Trailers and Installation of Tie-In for GTG Fuel Gas Interconnect, dated May 21, 2015 (Incorporated by reference to Exhibit 10.3 to Sabine Pass Liquefaction, LLC’s Quarterly Report on Form 10-Q (SEC File No. 333-192373), filed on July 30, 2015)
10.12	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-00001 Currency and Fuel Provisional Sum Adjustment, dated June 25, 2015 (Portions of this exhibit have been omitted and filed separately with the SEC pursuant to a request for confidential treatment) (Incorporated by reference to Exhibit 10.4 to Sabine Pass Liquefaction, LLC’s Quarterly Report on Form 10-Q (SEC File No. 333-192373), filed on July 30, 2015)
10.13	Second Amended and Restated Credit Agreement (Term Loan A), dated as of June 30, 2015, among Sabine Pass Liquefaction, LLC, as Borrower, Société Générale, as the Commercial Banks Facility Agent and the Common Security Trustee, and the lenders from time to time party thereto (Incorporated by reference to Exhibit 10.1 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on July 1, 2015)
10.14	Second Amended and Restated Common Terms Agreement, dated as of June 30, 2015, 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 10.2 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on July 1, 2015)
10.15	KEXIM Direct Facility Agreement, dated as of June 30, 2015, among Sabine Pass Liquefaction, LLC, as Borrower, The Export-Import Bank of Korea, a governmental financial institution of the Republic of Korea (“KEXIM”), as the KEXIM Direct Facility Lender, Shinhan Bank New York Branch, as the KEXIM Facility Agent, and Société Générale, as the Common Security Trustee (Incorporated by reference to Exhibit 10.3 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on July 1, 2015)
10.16	KEXIM Covered Facility Agreement, dated as of June 30, 2015, among Sabine Pass Liquefaction, LLC, as Borrower, Shinhan Bank New York Branch, as the KEXIM Facility Agent, Société Générale, as the Common Security Trustee, KEXIM and the lenders from time to time party thereto (Incorporated by reference to Exhibit 10.4 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on July 1, 2015)
10.17	Amended and Restated KSURE Covered Facility Agreement, dated as of June 30, 2015, among Sabine Pass Liquefaction, LLC, as Borrower, The Korea Development Bank, New York Branch, as the KSURE Covered Facility Agent, Société Générale, as the Common Security Trustee, and the lenders from time to time party thereto (Incorporated by reference to Exhibit 10.5 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on July 1, 2015)
10.18†	Cheniere Energy, Inc. Retirement Policy (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on June 17, 2015)
10.19	Amendment No. 1 to Meg Gentle's Assignment Letter, dated June 17, 2015 (Incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on June 17, 2015)
10.20*†	Form of Restricted Stock Grant under the Cheniere Energy, Inc. 2011 Incentive Plan (Director)
10.21†	Cheniere Energy, Inc. 2015 Long-Term Cash Incentive Plan (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on April 24, 2015)
10.22*	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-00001 Cost Impacts Associated with Delay in NTP, dated March 9, 2015, (2) the Change Order CO-00002 DLE/IAC Scope Change, dated March 25, 2015, (3) the Change Order CO-00003 Currency and Fuel Provisional Sum Closures, dated May 13, 2015 and (4) the Change Order CO-00004 Bridging Extension Through May 17, 2015, dated May 12, 2015 (Portions of this exhibit have been omitted and filed separately with the SEC pursuant to a request for confidential treatment)
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

44

Exhibit No.	Description
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

45

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:	July 30, 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:	July 30, 2015	By:	/s/ Leonard Travis
			Leonard Travis
			Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

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EX-3.1

Exhibit 3.1

AMENDED AND RESTATED BYLAWS

OF

CHENIERE ENERGY, INC.

ARTICLE I.

OFFICES

SECTION 1.1. Registered Office. Unless and until otherwise determined by the Board of Directors of Cheniere Energy, Inc. (the “Corporation”), the registered office of the Corporation in the State of Delaware shall be at the office of Corporation Service Company. The address of the registered office of the Company in the State of Delaware is 2711 Centerville Road, Suite 400, Wilmington, Delaware 19808, County of New Castle, and the registered agent in charge thereof shall be Corporation Service Company.

SECTION 1.2. Other Offices. The Corporation may also have an office or offices at any other place or places within or without the State of Delaware as the Board of Directors of the Corporation (the “Board”) may from time to time determine or the business of the Corporation may from time to time require.

ARTICLE II.

MEETING OF STOCKHOLDERS

SECTION 2.1. Place of Meetings. Meetings of the stockholders for the election of directors or for any other purpose shall be held at such time and place, either within or without the State of Delaware, as shall be designated from time to time by the Board. The Board may, in its sole discretion, determine that a meeting of the stockholders shall not be held at any place, but may instead be held solely by means of remote communication in the manner authorized by the General Corporation Law of the State of Delaware (the “General Corporation Law”).

SECTION 2.2. Annual Meetings. If required by applicable law, the annual meeting of stockholders of the Corporation for the election of directors of the Corporation (“Directors”) and for the transaction of such other business as may properly come before such meeting, shall be held on such date and at such time as shall be fixed from time to time by resolution of the Board. The Board may postpone, reschedule or cancel any annual meeting of stockholders previously scheduled by the Board.

SECTION 2.3. Special Meetings. Unless otherwise required by law or by the amended and restated certificate of incorporation of the Corporation, as it may be amended and restated from time to time (the “Certificate of Incorporation”), special meetings of stockholders for any purpose or purposes may be called by any of (i) the Board, (ii) the Chairman of the Board of the Corporation (the “Chairman”), if any, (iii) the Chief Executive Officer, (iv) the President or (v) the Secretary of the Corporation (the “Secretary”) at the request in writing of a majority of the Board and shall be called by the Board upon written request to the Secretary by the record holder or holders of at least 50.1% of the outstanding shares of common stock of the Corporation (the “Requisite Percentage”), who have complied in full with the requirements set forth in these Bylaws (such request, a “Stockholder Meeting Request”). A special meeting of stockholders may be held at such date, time and place, if any, within or without the State of Delaware as may be designated from time to time by the Board; provided, however, that the date of any such special meeting called upon the receipt of a Stockholder Meeting Request shall be not more than 90 days after the Special Meeting Request is received by the Secretary. In fixing a date, time and place, if any, for any special meeting of stockholders,

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the Board may consider such factors as it deems relevant, including without limitation, the nature of the matters to be considered, the facts and circumstances related to any request for a meeting and any plan of the Board to call an annual meeting or special meeting. The Board may postpone, reschedule or cancel any special meeting of stockholders previously scheduled by the Board.

A Stockholder Meeting Request shall be delivered to the Secretary and shall be signed by each stockholder, or a duly authorized agent of such stockholder, requesting the special meeting and shall be accompanied by a written notice setting forth the information required by (i) Section 2.13 of these Bylaws as to the business proposed to be conducted at the special meeting and as to the stockholder(s) proposing such business and/or as to any nominations proposed to be presented at the special meeting and as to the stockholder(s) proposing such nominations. In addition to the foregoing, a Stockholder Meeting Request must include (x) an acknowledgment of the requesting stockholder(s) that any disposition by such stockholder(s) after the date of the Stockholder Meeting Request of any shares of the Corporation’s common stock shall be deemed a revocation of the Stockholder Meeting Request with respect to such shares and that such shares will no longer be included in determining whether the Requisite Percentage has been satisfied, and (y) a commitment by such stockholder(s) to continue to satisfy the Requisite Percentage through the date of the requested special meeting of stockholders and to notify the Corporation upon any disposition of any shares of the Corporation’s common stock. The requesting stockholder(s) shall certify in writing on the day prior to the requested special meeting of stockholders as to whether the requesting stockholder(s) continue to satisfy the Requisite Percentage. In addition to the foregoing, the requesting stockholder(s) shall promptly provide any other information reasonably requested by the Corporation.

In determining whether a special meeting of stockholders has been requested by the record holders of shares representing in the aggregate at least the Requisite Percentage, multiple Special Meeting Requests delivered to the Secretary will be considered together only if (i) each Special Meeting Request identifies substantially the same purpose or purposes of the special meeting and substantially the same matters proposed to be acted on at the special meeting, in each case as determined by the Board (which, if such purpose is the nominating of a person or persons for election to the Board, will mean that the exact same person or persons are nominated in each relevant Stockholder Meeting Request), and (ii) such Special Meeting Requests have been dated and delivered to the Secretary within 60 days of the earliest dated Special Meeting Request. A stockholder may revoke a Special Meeting Request at any time by written revocation delivered to the Secretary. If, following such revocation, there are unrevoked requests from stockholders holding in the aggregate less than the Requisite Percentage, the Board, in its discretion, may cancel the special meeting. If none of the requesting stockholder(s) who submitted the Special Meeting Request appears or sends a qualified representative to present the matters to be presented for consideration that were specified in the Stockholder Meeting Request, the Corporation need not present such matters for a vote at such meeting, notwithstanding that proxies in respect of such matter may have been received by the Corporation.

At any special meeting requested by stockholders, the business transacted shall be limited to the purpose(s) stated in the Stockholder Meeting Request; provided, however, that the Board shall have the authority in its discretion to submit additional matters to the stockholders and to cause other business to be transacted. Notwithstanding the foregoing provisions of this Section 2.3, a special meeting of stockholders requested by stockholders shall not be held if (i) the business specified in the Special Meeting Request is not a proper subject for stockholder action under applicable law (as determined by the Board), (ii) the Board has called or calls for an annual or special meeting of stockholders to be held within 90 days after the Secretary receives the Stockholder Meeting Request and the Board determines that the business of such meeting includes (among any other matters properly brought before the annual meeting) the business specified in the Stockholder Meeting Request, (iii) the Stockholder Meeting Request is received by the Secretary during the period commencing 90 days prior to the anniversary date of the prior year’s annual meeting of stockholders

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and ending on the date of the next annual meeting of stockholders, (iv) an identical or substantially similar item (a “Similar Item”) was presented at any meeting of stockholders held within 90 days prior to receipt by the Secretary of the Stockholder Meeting Request (and, for purposes of this clause (iv), the nomination, election or removal of Directors shall be deemed a “Similar Item” with respect to all items of business involving the nomination, election or removal of Directors, the changing the size of the Board and the filling of vacancies and/or newly created directorships), or (v) the Stockholder Meeting Request was made in a manner that involved a violation of Regulation 14A under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) or other applicable law.

SECTION 2.4. Notice of Meetings. Whenever stockholders are required or permitted to take action at a meeting, a written notice of the meeting of stockholders shall be given stating the place, if any, date and time of such meeting, the means of remote communications, if any, by which stockholders and proxy holders may be deemed to be present in person and vote at such meeting, the record date for determining stockholders entitled to vote at the meeting or any adjournment thereof (if such record date is different from the record date for determining the stockholders entitled to notice of the meeting) and, in the case of a special meeting, the purpose or purposes for which such meeting is to be held. Unless otherwise provided by law, the Certificate of Incorporation or these Bylaws, the notice of any meeting shall be given to each stockholder entitled to notice of the meeting as of the record date for determining stockholders entitled to notice of the meeting, not less than 10 nor more than 60 days before the date of such meeting. If mailed, such notice shall be deemed to be given when deposited in the United States mail, postage prepaid, directed to the stockholder at such stockholder’s address as it appears on the records of the Corporation. If, prior to the time of transmittal of notice, the Secretary shall have received from any stockholder a written request that notices intended for such stockholder are to be transmitted to some address other than the address that appears on the records of the Corporation, notices intended for such stockholder shall be transmitted to the address designated in such request.

Notice of a special meeting of stockholders may be given by the person or persons calling the meeting, or, upon the written request of such person or persons, such notice shall be given by the Secretary on behalf of such person or persons. If the person or persons calling a special meeting of stockholders give notice thereof, such person or persons shall deliver a copy of such notice to the Secretary. Each request to the Secretary for the giving of notice of a special meeting of stockholders shall state the purpose or purposes of such meeting.

Whenever notice is required to be given under any statute or the Certificate of Incorporation or these Bylaws to any stockholder to whom (1) notice of two consecutive annual meetings, and all notice of meetings or of the taking of action by written consent without a meeting to such person during the period between such two consecutive annual meetings or (2) all, and at least two, payments (if sent by first class mail) of dividends or interest on securities during a twelve month period, have been mailed addressed to such person at his or her address as shown on the records of the Corporation and have been returned because undeliverable, the giving of notice to such person shall not be required. Any action or meeting which shall be taken or held without notice to such person shall have the same force and effect as if such notice had been duly given. If any such person shall deliver to the Corporation a written notice setting forth his or her then current address, the requirement that notice be given to such person shall be reinstated. In the event that the action taken by the Corporation is such as to require the filing of a certificate under any of the other sections of the General Corporation Law, the certificate need not state that notice was not given to persons to whom notice was not required to be given pursuant to this Section 2.4.

SECTION 2.5. Waiver of Notice. Any waiver of notice of any annual or special meeting of stockholders given by the stockholder entitled to notice, whether before or after such meeting, shall be

3

deemed equivalent to notice. Neither the business to be transacted at, nor the purpose of, any meeting of stockholders need be specified in any waiver of notice thereof. Attendance of a stockholder at a meeting shall constitute a waiver of notice of such meeting, except when such stockholder attends a meeting for the express purpose of objecting, at the beginning of the meeting, to the transaction of any business because the meeting is not lawfully called or convened.

SECTION 2.6. Adjournments. Any stockholders’ meeting, annual or special, whether or not a quorum (as defined in Section 2.7 hereinafter) is present, may be adjourned from time to time to reconvene at the same or some other place, and notice need not be given of the adjourned meeting if the date, time and place thereof are announced at the meeting at which the adjournment is taken. If the adjournment is for more than 30 days, or if after the adjournment a new record date for determining stockholders entitled to vote is fixed for the adjourned meeting, a notice of the adjourned meeting in accordance with the requirements of Section 2.4 hereof shall be given to each stockholder entitled to vote thereat. At the adjourned meeting, any business may be transacted which might have been transacted at the original meeting.

SECTION 2.7. Quorum. Except as otherwise provided by law, the Certificate of Incorporation or these Bylaws, at each meeting of stockholders, the holders of a majority in voting power of the outstanding shares of stock entitled to vote thereat, present in person or by proxy, shall constitute a quorum for the transaction of business at the meetings. Abstentions and broker non-votes shall be deemed to be shares present for quorum purposes. If, however, such quorum shall not be present in person or by proxy at any meeting of stockholders, the stockholders entitled to vote thereat, present in person or by proxy, may, by a majority in voting power thereof, adjourn the meeting from time to time in accordance with Section 2.6 of these Bylaws until a quorum shall be present in person or by proxy. The stockholders present at a duly called or held meeting at which a quorum is present may continue to do business until adjournment, notwithstanding the withdrawal of enough stockholders to leave less than a quorum.

SECTION 2.8. Voting. Except as otherwise provided by the Certificate of Incorporation, each stockholder entitled to vote at any meeting of stockholders shall be entitled to one vote for each share held by such stockholder which has voting power upon the matter in question. On any matter where a minimum or other vote of stockholders is provided by the Certificate of Incorporation, these Bylaws, the rules or regulations of any stock exchange applicable to the Corporation, or applicable law or pursuant to any regulation applicable to the Corporation or its securities, such minimum or other vote shall be the required vote on such matter (with the effect of abstentions and broker non-votes to be determined based on the vote required). All other matters presented to the stockholders at a meeting at which a quorum is present for which no minimum or other vote is called for by the Certificate of Incorporation, these Bylaws, the rules or regulations of any stock exchange applicable to the Corporation, or applicable law or pursuant to any regulation applicable to the Corporation or its securities, other than for the election of Directors, shall be decided by the affirmative vote of the holders of a majority in voting power of the shares of stock entitled to vote on the matter, present in person or by proxy (with abstentions counting as votes against the matter and broker non-votes not counting as shares entitled to vote on the matter).

Subject to the rights of the holders of any series of preferred stock to elect Directors under specified circumstances, each Director shall be elected by the vote of a majority of votes cast with respect to that Director’s election at any meeting for the election of Directors at which a quorum is present, provided that if, as of the tenth (10th) day preceding the date the Corporation first mails its notice of meeting for such meeting to the stockholders, the number of nominees exceeds the number of Directors to be elected (a “Contested Election”), the Directors shall be elected by the vote of a plurality of the votes cast. For purposes of this Section 2.8, a “majority of votes cast” shall mean that the number of votes cast “for” a Director’s

4

election exceeds the number of votes cast “against” that Director’s election (with “abstentions” and “broker non-votes” not counted as votes cast either “for” or “against” that Director’s election). In the event an incumbent Director fails to receive a majority of votes cast in an election that is not a Contested Election, such incumbent Director shall submit to the Company, in accordance with Section 3.4 of these Bylaws, such director’s resignation from the Board, contingent on acceptance of that resignation by the Board. The Governance and Nominating Committee shall make a recommendation to the Board as to whether to accept or reject the resignation of such incumbent Director, or whether other action should be taken. The Board shall act on the resignation, taking into account the Governance and Nominating Committee’s recommendation, and publicly disclose (by a press release and filing an appropriate disclosure with the Securities and Exchange Commission) its decision regarding the resignation (and, if such resignation is rejected, the rationale behind the decision) within ninety (90) days following certification of the election results. The Director whose resignation is being considered shall not participate in the deliberations of the Governance and Nominating Committee or the Board with respect to whether to accept such director’s resignation. If the Director’s resignation is not accepted by the Board, such Director shall continue to serve until his or her successor is duly elected, or until his or her earlier resignation or removal. If the Board accepts a Director’s resignation pursuant to this Section 2.8, or if a nominee for Director is not elected and the nominee is not an incumbent Director, then the Board may fill the resulting vacancy pursuant to Article III, Section 3.3 of these Bylaws.

Notwithstanding the foregoing provisions of this Section 2.8, on any compensation-related matter presented to the stockholders on or before September 17, 2022 at a meeting at which a quorum is present, then such compensation-related matter shall be decided by the affirmative vote of the holders of a majority in voting power of the shares of stock entitled to vote on the matter, present in person or by proxy (with abstentions counting as votes against the matter and broker non-votes not counting as shares entitled to vote on the matter).

SECTION 2.9. Proxies. Each stockholder entitled to vote at a meeting of stockholders may authorize another person or persons to act for such stockholder by proxy. Such proxy shall be filed with the Secretary before such meeting of stockholders at such time as the Board may require. No proxy shall be voted or acted upon after three years from its date, unless the proxy provides for a longer period. A proxy shall be irrevocable if it states that it is irrevocable and if, and only as long as, it is coupled with an interest sufficient in law to support an irrevocable power. A stockholder may revoke any proxy which is not irrevocable by attending the meeting and voting in person or by delivering to the Secretary a revocation of the proxy or a new proxy bearing a later date. Voting at meetings of stockholders need not be by written ballot.

SECTION 2.10. Organization. Meetings of stockholders shall be presided over by the Chairman, if any, or in his or her absence by the Vice Chairman of the Board, if any, or in his or her absence by the President, or in his or her absence by a Vice President, or in the absence of the foregoing persons by a chairman designated by the Board, or in the absence of such designation by a chairman chosen at the meeting. The Secretary shall act as secretary of the meeting, but in his or her absence the chairman of the meeting may appoint any person to act as secretary of the meeting.

SECTION 2.11. List of Stockholders Entitled to Vote. The officer of the Corporation who has charge of the stock ledger of the Corporation shall prepare and make, at least ten (10) days before every meeting of stockholders, a complete list of the stockholders entitled to vote at the meeting (provided, however, if the record date for determining the stockholders entitled to vote is less than ten (10) days before the date of the meeting, the list shall reflect the stockholders entitled to vote as of the tenth day before the meeting date), arranged in alphabetical order, and showing the address of each stockholder and the number of shares registered in the name of each stockholder. Such list shall be open to the examination of any stockholder,

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for any purpose germane to the meeting at least ten (10) days prior to the meeting (i) on a reasonably accessible electronic network, provided that the information required to gain access to such list is provided with the notice of meeting or (ii) during ordinary business hours at the principal place of business of the Corporation. If the meeting is to be held at a place, then a list of stockholders entitled to vote at the meeting shall be produced and kept at the time and place of the meeting during the whole time thereof and may be examined by any stockholder who is present. If the meeting is to be held solely by means of remote communication, then the list shall also be open to the examination of any stockholder during the whole time of the meeting on a reasonably accessible electronic network, and the information required to access such list shall be provided with the notice of the meeting. Except as otherwise provided by law, the stock ledger shall be the only evidence as to who are the stockholders entitled to examine the list of stockholders required by this Section 2.11 or to vote in person or by proxy at any meeting of stockholders.

SECTION 2.12. Conduct of Meetings. The date and time of the opening and the closing of the polls for each matter upon which the stockholders will vote at a meeting shall be announced at the meeting by the chairman of the meeting. The Board may adopt by resolution such rules and regulations for the conduct of the meeting of stockholders as it shall deem appropriate. Except to the extent inconsistent with such rules and regulations as adopted by the Board, the chairman of the meeting shall have the right and authority to convene and (for any or no reason) to recess and/or adjourn the meeting of stockholders, to prescribe such rules, regulations and procedures and to do all such acts as, in the judgment of such chairman, are appropriate for the proper conduct of the meeting. Such rules, regulations or procedures, whether adopted by the Board or prescribed by the chairman of the meeting, may include, without limitation, the following: (i) the establishment of an agenda or order of business for the meeting; (ii) rules and procedures for maintaining order at the meeting and the safety of those present; (iii) limitations on attendance at or participation in the meeting to stockholders entitled to vote at the meeting, their duly authorized and constituted proxies or such other persons as the chairman of the meeting shall determine; (iv) restrictions on entry to the meeting after the time fixed for the commencement thereof; and (v) limitations on the time allotted to questions or comments by participants. The chairman of the meeting of stockholders, in addition to making any other determinations that may be appropriate to the conduct of the meeting, shall, if the facts warrant, determine and declare to the participants of the meeting that a nomination or matter or business was not properly brought before the meeting and if such chairman should so determine, such chairman shall so declare to the participants of the meeting and any such matter or business not properly brought before the meeting shall not be transacted or considered. Unless and to the extent determined by the Board or the chairman of the meeting, meetings of stockholders shall not be required to be held in accordance with the rules of parliamentary procedure.

SECTION 2.13. Notice of Stockholder Business and Nominations.

(A) Annual Meetings of Stockholders. (1) Nominations of persons for election to the Board and the proposal of other business to be considered by the stockholders may be made at an annual meeting of stockholders only (a) pursuant to the Corporation’s notice of meeting (or any supplement thereto), (b) by or at the direction of the Board or any duly authorized committee thereof or (c) by any stockholder of the Corporation who was a stockholder of record of the Corporation at the time the notice provided for in this Section 2.13 is delivered to the Secretary, who is entitled to vote at the meeting and upon such election or proposed business and who complies with the notice procedures set forth in this Section 2.13.

(2) For any nominations or other business to be properly brought before an annual meeting by a stockholder pursuant to clause (c) of paragraph (A)(1) of this Section 2.13, the stockholder must have given timely notice thereof in writing to the Secretary and any such proposed business (other than the nominations of persons for election to the Board) must constitute a proper matter for stockholder action. To be timely, a stockholder’s notice shall be delivered to the Secretary at the principal executive offices of the

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Corporation not later than the close of business on the ninetieth (90th) day, nor earlier than the close of business on the one hundred twentieth (120th) day, prior to the first anniversary of the preceding year’s annual meeting (provided, however, that in the event that the date of the annual meeting is more than thirty (30) days before or more than seventy (70) days after such anniversary date, notice by the stockholder must be so delivered not earlier than the close of business on the one hundred twentieth (120th) day prior to such annual meeting and not later than the close of business on the later of the ninetieth (90th) day prior to such annual meeting or the tenth (10th) day following the day on which public announcement of the date of such meeting is first made by the Corporation). In no event shall the public announcement of an adjournment or postponement of an annual meeting commence a new time period (or extend any time period) for the giving of a stockholder’s notice as described above. Such stockholder’s notice shall set forth: (a) as to the stockholder giving the notice and the beneficial owner, if any, on whose behalf the nomination or proposal is made (i) the name and address of such stockholder, as they appear on the Corporation’s books, and of such beneficial owner, (ii) the class or series and number of shares of capital stock of the Corporation which are owned beneficially and of record by such stockholder and such beneficial owner, (iii) a description of any agreement, arrangement or understanding with respect to the nomination or proposal between or among such stockholder and/or such beneficial owner, any of their respective affiliates or associates, and any others acting in concert with any of the foregoing, including, in the case of a nomination, the nominee, (iv) a description of any agreement, arrangement or understanding (including any derivative or short positions, profit interests, options, warrants, convertible securities, stock appreciation or similar rights, hedging transactions, and borrowed or loaned shares) that has been entered into as of the date of the stockholder’s notice by, or on behalf of, such stockholder and such beneficial owners, whether or not such instrument or right shall be subject to settlement in underlying shares of capital stock of the corporation, the effect or intent of which is to mitigate loss to, manage risk or benefit of share price changes for, or increase or decrease the voting power of, such stockholder or such beneficial owner, with respect to securities of the Corporation, (v) with respect to a nomination, any material interest of such stockholder and/or such beneficial owner, if any, in such nomination, (vi) a representation that the stockholder is a holder of record of stock of the Corporation entitled to vote at such meeting and intends to appear in person or by proxy at the meeting to propose such business or nomination, (vii) a representation whether the stockholder or the beneficial owner, if any, intends or is part of a group which intends (a) to deliver a proxy statement and/or form of proxy to holders of at least the percentage of the Corporation’s outstanding capital stock required to approve or adopt the proposal or elect the nominee and/or (b) otherwise to solicit proxies or votes from stockholders in support of such proposal or nomination, and (viii) any other information relating to such stockholder and beneficial owner, if any, required to be disclosed in a proxy statement or other filings required to be made in connection with solicitations of proxies for, as applicable, the proposal and/or for the election of directors in an election contest pursuant to and in accordance with Section 14(a) of the Exchange Act and the rules and regulations promulgated thereunder; (b) as to each person whom the stockholder proposes to nominate for election as a director (i) the name, address and principal occupation of such person, (ii) the class or series and number of shares of capital stock of the Corporation which are owned beneficially and of record by such person, (iii) a description of any agreement, arrangement or understanding with respect to the nomination entered into by such person and any others acting in concert with such person, (iv) a description of any agreement, arrangement or understanding (including any derivative or short positions, profit interests, options, warrants, convertible securities, stock appreciation or similar rights, hedging transactions, and borrowed or loaned shares) that has been entered into as of the date of the stockholder’s notice by, or on behalf of, such person, whether or not such instrument or right shall be subject to settlement in underlying shares of capital stock of the Corporation, the effect or intent of which is to mitigate loss to, manage risk or benefit of share price changes for, or increase or decrease the voting power of, such person, with respect to securities of the Corporation, (v) all information relating to such person that is required to be disclosed in solicitations of proxies for election of directors in an election contest, or is otherwise required, in each case pursuant to and in accordance with Section 14(a) of the Exchange Act, and the rules and regulations promulgated thereunder,

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(vi) such person’s written consent to being named in the proxy statement as a nominee and to serving as a director if elected and (vii) such person’s written representation that such person (A) is not and will not become a party to any compensatory, payment or other financial agreement, arrangement or understanding with any person or entity other than the Corporation, in each case in connection with candidacy, election or service as a director of the Corporation other than agreements providing only for indemnification and/or reimbursement of out-of-pocket expenses in connection with candidacy or election as a director (but not, for the avoidance of doubt, in connection with service as a director) or any pre-existing employment agreement a candidate has with his or her employer (not entered into in contemplation of the employer’s investment in the Corporation or such employee’s candidacy as a director), (B) is not and will not become a party to any agreement, arrangement or understanding with, and has not given any commitment or assurance to, any person or entity as to how such person, if elected as a director of the Corporation, will act or vote on any issue or question and (C) if elected as a director of the Corporation, will comply with all policies and guidelines of the Corporation that are applicable to directors of the Corporation; and (c) as to any other business that the stockholder proposes to bring before the meeting, a brief description of the business desired to be brought before the meeting, the text of the proposal or business (including the text of any resolutions proposed for consideration and in the event that such business includes a proposal to amend the Bylaws of the Corporation, the language of the proposed amendment), the reasons for conducting such business at the meeting and any material interest in such business of such stockholder and the beneficial owner, if any, on whose behalf the proposal is made. The Corporation may require any proposed nominee to furnish such other information as the Corporation may reasonably require to determine the eligibility of such proposed nominee to serve as a director of the Corporation.

(3) Notwithstanding anything in the second sentence of paragraph (A)(2) of this Section 2.13 to the contrary, in the event that the number of directors to be elected to the Board at the annual meeting is increased effective after the time period for which nominations would otherwise be due under paragraph (A)(2) of this Section 2.13 and there is no public announcement by the Corporation naming the nominees for the additional directorships at least one hundred (100) days prior to the first anniversary of the preceding year’s annual meeting, a stockholder’s notice required by this Section 2.13 shall also be considered timely, but only with respect to nominees for the additional directorships, if it shall be delivered to the Secretary at the principal executive offices of the Corporation not later than the close of business on the tenth (10th) day following the day on which such public announcement is first made by the Corporation.

(B) Special Meetings of Stockholders. Only such business shall be conducted at a special meeting of stockholders as shall have been brought before the meeting pursuant to the Corporation’s notice of meeting. Nominations of persons for election to the Board may be made at a special meeting of stockholders at which directors are to be elected pursuant to the Corporation’s notice of meeting (1) by or at the direction of the Board or any duly authorized committee thereof or (2) provided that the Board has determined that directors shall be elected at such meeting, by any stockholder of the Corporation who is a stockholder of record at the time the notice provided for in this Section 2.13 is delivered to the Secretary, who is entitled to vote at the meeting and upon such election and who complies with the notice procedures set forth in this Section 2.13. In the event the Corporation calls a special meeting of stockholders for the purpose of electing one or more directors to the Board, any such stockholder entitled to vote in such election of directors may nominate a person or persons (as the case may be) for election to such position(s) as specified in the Corporation’s notice of meeting, if the stockholder’s notice required by paragraph (A)(2) of this Section 2.13 shall be delivered to the Secretary at the principal executive offices of the Corporation not earlier than the close of business on the one hundred twentieth (120th) day prior to such special meeting and not later than the close of business on the later of the ninetieth (90th) day prior to such special meeting or the tenth (10th) day following the day on which public announcement is first made of the date of the special meeting and of the nominees proposed by the Board to be elected at such meeting. In no event shall the public announcement of an

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adjournment or postponement of a special meeting commence a new time period (or extend any time period) for the giving of a stockholder’s notice as described above.

(C) General. (1) Except as otherwise expressly provided in any applicable rule or regulation promulgated under the Exchange Act, only such persons who are nominated in accordance with the procedures set forth in this Section 2.13 shall be eligible to be elected at an annual or special meeting of stockholders of the Corporation to serve as directors and only such business shall be conducted at a meeting of stockholders as shall have been brought before the meeting in accordance with the procedures set forth in this Section 2.13. Except as otherwise provided by law, the chairman of the meeting shall have the power and duty (a) to determine whether a nomination or any business proposed to be brought before the meeting was made or proposed, as the case may be, in accordance with the procedures set forth in this Section 2.13 (including whether the stockholder or beneficial owner, if any, on whose behalf the nomination or proposal is made solicited (or is part of a group which solicited) or did not so solicit, as the case may be, proxies or votes in support of such stockholder’s nominee or proposal in compliance with such stockholder’s representation as required by clause (A)(2)(a)(vii) of this Section 2.13) and (b) if any proposed nomination or business was not made or proposed in compliance with this Section 2.13, to declare that such nomination shall be disregarded or that such proposed business shall not be transacted. Notwithstanding the foregoing provisions of this Section 2.13, unless otherwise required by law, if the stockholder (or a qualified representative of the stockholder) does not appear at the annual or special meeting of stockholders of the Corporation to present a nomination or proposed business, such nomination shall be disregarded and such proposed business shall not be transacted, notwithstanding that proxies in respect of such vote may have been received by the Corporation. For purposes of this Section 2.13, to be considered a qualified representative of the stockholder, a person must be a duly authorized officer, manager or partner of such stockholder or must be authorized by a writing executed by such stockholder or an electronic transmission delivered by such stockholder to act for such stockholder as proxy at the meeting of stockholders and such person must produce such writing or electronic transmission, or a reliable reproduction of the writing or electronic transmission, at the meeting of stockholders.

(2)A stockholder providing notice of any nomination proposed to be made at an annual meeting or special meeting shall further update and supplement such notice, if necessary, so that the information provided or required to be provided in such notice pursuant to this Section 2.13 shall be true and correct as of the record date for determining the stockholders entitled to receive notice of the annual meeting or special meeting, and such update and supplement shall be delivered to or be mailed and received by the Secretary at the principal executive offices of the Corporation not later than five (5) business days after the record date for determining the stockholders entitled to receive notice of such annual meeting or special meeting.

(3) For purposes of this Section 2.13, “public announcement” shall include disclosure in a press release reported by the Dow Jones News Service, Associated Press or other national news service or in a document publicly filed by the corporation with the Securities and Exchange Commission pursuant to Section 13, 14 or 15(d) of the Exchange Act and the rules and regulations promulgated thereunder.

(4) Notwithstanding the foregoing provisions of this Section 2.13, a stockholder shall also comply with all applicable requirements of the Exchange Act and the rules and regulations promulgated thereunder with respect to the matters set forth in this Section 2.13; provided however, that any references in these Bylaws to the Exchange Act or the rules and regulations promulgated thereunder are not intended to and shall not limit any requirements applicable to nominations or proposals as to any other business to be considered pursuant to this Section 2.13 (including paragraphs (A)(1)(c) and (B) hereof), and compliance with paragraphs (A)(1)(c) and (B) of this Section 2.13 shall be the exclusive means for a stockholder to make

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nominations or submit business other than nominations (other than, as provided in the penultimate sentence of (A)(2), business other than nominations brought properly under and in compliance with Rule 14a-8 of the Exchange Act, as may be amended from time to time). Nothing in this Section 2.13 shall be deemed to affect any rights (a) of stockholders to request inclusion of proposals or nominations in the corporation’s proxy statement pursuant to applicable rules and regulations promulgated under the Exchange Act or (b) of the holders of any series of preferred stock to elect directors pursuant to any applicable provisions of the Certificate of Incorporation.

SECTION 2.14. Inspectors of Election. The Corporation shall, in advance of any meeting of stockholders, appoint one or more inspectors of election, who may be officers, employees or agents of the Corporation, to act at the meeting or any adjournment thereof and to make a written report thereof. The Corporation may designate one or more persons as alternate inspectors to replace any inspector who fails to act. In the event that no inspector so appointed or designated is able to act at a meeting of stockholders, the chairman of the meeting shall appoint one or more inspectors to act at the meeting. Each inspector, before entering upon the discharge of his or her duties, shall take and sign an oath faithfully to execute the duties of inspector with strict impartiality and according to the best of his or her ability. The inspector or inspectors so appointed or designated shall (i) ascertain the number of shares of capital stock of the Corporation outstanding and the voting power of each such share, (ii) determine the shares of capital stock of the Corporation represented at the meeting and the validity of proxies and ballots, (iii) count all votes and ballots, (iv) determine and retain for a reasonable period a record of the disposition of any challenges made to any determination by the inspectors, and (v) certify their determination of the number of shares of capital stock of the Corporation represented at the meeting and such inspectors’ count of all votes and ballots. Such certification and report shall specify such other information as may be required by law. In determining the validity and counting of proxies and ballots cast at any meeting of stockholders of the Corporation, the inspectors may consider such information as is permitted by applicable law. No person who is a candidate for an office at an election may serve as an inspector at such election.

ARTICLE III.

BOARD OF DIRECTORS

SECTION 3.1. General Powers. Except as may otherwise be provided by law or in the Certificate of Incorporation, the business and affairs of the Corporation shall be managed by or under the direction of the Board, which may exercise all such powers of the Corporation and do all such lawful acts and things as are not by law, the Certificate of Incorporation or these Bylaws directed or required to be exercised or done by the stockholders.

SECTION 3.2. Number and Term of Office. The number of Directors shall be determined from time to time by the Board. Directors need not be stockholders. Directors shall be elected at the annual meeting of stockholders. As provided in the Certificate of Incorporation, until the election of Directors at the 2013 annual meeting of stockholders, the Board shall be divided into three classes: Class I, Class II and Class III, with the Directors in Class I having a term expiring at the 2014 annual meeting of stockholders, the Directors in Class II having a term expiring at the 2015 annual meeting and the Directors in Class III having a term expiring at the 2013 annual meeting. From and after the election of Directors at the 2013 annual meeting, the Board shall cease to be classified, and the Directors shall be elected at each annual meeting to hold office for a term expiring at the next annual meeting and until such director’s successor is duly elected and qualified, or until such director’s earlier death, resignation or removal; provided, however, that each Director elected at the 2011 annual meeting and the 2012 annual meeting shall serve for the full three-year term to which such Director was elected. Notwithstanding anything to the contrary contained in this Article III, the manner

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of election, terms of office and other provisions relating to Directors shall be as provided in the Certificate of Incorporation.

SECTION 3.3. Vacancies and Newly Created Directorships. Subject to applicable law and the rights of holders of any series of preferred stock to elect additional Directors under specified circumstances, vacancies on the Board, and newly created directorships resulting from any increase in the authorized number of Directors, may be filled only by the affirmative vote of a majority of the Directors then in office, though less than a quorum, and not by stockholders. Any Director so chosen to fill a vacancy in a class or a newly created directorship of a class prior to the 2013 annual meeting shall hold office for a term that shall coincide with the remaining term of that class. Any Director so chosen to fill a vacancy or a newly created directorship at or following the 2013 annual meeting shall hold office for a term expiring at the next annual meeting and until such director’s successor is duly elected and qualified, or until such director’s earlier death, resignation or removal. No decrease in the authorized number of Directors constituting the Board shall shorten the term of any incumbent Director. Notwithstanding the foregoing provisions of this Section 3.3, any vacancy on the Board that results from the removal of a Director from office for cause prior to the 2013 annual meeting may be filled only by the affirmative vote of a majority of the stockholders of the Company at a meeting called for that purpose or, if not filled by the stockholders, by the affirmative vote of a majority of the Directors then in office, though less than a quorum.

SECTION 3.4. Resignation. Any Director may resign from the Board or any committee thereof at any time by giving written notice to the Board, the Chairman, if any, or the Secretary and, in the case of a committee, to the committee chair of such committee, if any. Such resignation shall take effect at the time specified in such notice or, if the time be not specified, upon receipt thereof by the Board, the Chairman or the Secretary, as the case may be. Unless otherwise specified therein, acceptance of such resignation shall not be necessary to make it effective.

SECTION 3.5. Removal. Subject to the rights of the holders of any series of preferred stock then outstanding, any Director, or the entire Board, may be removed from office (i) at any time prior to the 2013 annual meeting, but only for cause, and (ii) at any time at or after the 2013 annual meeting, with or without cause.

SECTION 3.6. Meetings. Regular Meetings. As soon as practicable after each annual meeting of the stockholders, the Board shall meet for the purpose of organization and the transaction of other business, unless it shall have transacted all such business by written consent pursuant to Section 3.8 hereof. Other regular meetings of the Board may be held at such places within or without the State of Delaware and at such times as the Board may from time to time determine.

(a) Special Meetings. Special meetings of the Board may be held at any time or place within or without the State of Delaware whenever called by the Chairman, the Vice Chairman, the President, the Secretary or by a majority of the Board.

(b) Notice of Meetings. Notice of each regular meeting of the Board held pursuant to this Section 3.6 on a date and at a time previously furnished to the Board shall not be required. Notice of each special meeting of the Board shall be given by the Secretary or the person calling the meeting at least twenty-four hours before the special meeting. Notice may be given in writing and delivered personally or mailed to the Directors at their addresses appearing on the books of the Corporation, by telecopier, by telephone or by other means of electronic transmission. A waiver of notice, whether in writing or by electronic transmission, signed by the Director entitled to notice, whether before or after the time of the meeting referred to in such waiver, shall be deemed equivalent to notice. Neither the business to be transacted at, nor the purpose of any

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meeting of the Board need be specified in any waiver of notice thereof. Attendance of a Director at a meeting of the Board shall constitute a waiver of notice of such meeting, except when such Director attends a meeting for the express purpose of objecting, at the beginning of the meeting, to the transaction of business because the meeting is not lawfully called or convened.

(c) Quorum and Manner of Acting. A majority of the total number of Directors then in office shall constitute a quorum for the transaction of business at such meeting. The vote of a majority of the Directors present at any such meeting at which a quorum is present shall be necessary for the passage of any resolution or act of the Board, except as otherwise expressly required by law, the Certificate of Incorporation or these Bylaws. In the absence of a quorum for any such meeting, a majority of the Directors present thereat may adjourn such meeting from time to time until a quorum shall be present.

(d) Organization. At each meeting of the Board, one of the following shall act as chairman of the meeting and preside, in the following order of precedence:

(i)the Chairman, if any;

(ii)the Vice Chairman, if any,

(iii)the President;

(iv)any Director chosen by a majority of the Directors present.

The Secretary or, in the case of his or her absence, any person (who shall be an Assistant Secretary, if an Assistant Secretary is present) who the chairman of the meeting shall appoint shall act as secretary of such meeting and keep the minutes thereof.

SECTION 3.7. Committees of the Board. The Corporation elects to be governed by Section 141(c)(2) of the General Corporation Law. The Board may designate one or more committees, each committee to consist of one or more Directors. The Board may designate one or more Directors as alternate members of any committee, who may replace any absent or disqualified member at any meeting of such committee. In the absence or disqualification of a member of a committee, the member or members thereof present at any meeting and not disqualified from voting, whether or not he, she or they constitute a quorum, may unanimously appoint another Director to act at the meeting in the place of any such absent or disqualified member. Any committee of the Board, to the extent permitted by law and to the extent provided in the resolution of the Board designating such committee, shall have and may exercise all the powers and authority of the Board in the management of the business and affairs of the Corporation, and may authorize the seal of the Corporation to be affixed to all papers which may require it.

SECTION 3.8. Directors’ Consent in Lieu of Meeting. Unless otherwise restricted by the Certificate of Incorporation or these Bylaws, any action required or permitted to be taken at any meeting of the Board or of any committee thereof may be taken without a meeting, without prior notice and without a vote, if a consent in writing or by electronic transmission, setting forth the action so taken, shall be signed by all the members of the Board or such committee and such consent is filed with the minutes of the proceedings of the Board or such committee.

SECTION 3.9. Action by Means of Telephone or Similar Communications Equipment. Any one or more members of the Board, or of any committee thereof, may participate in a meeting of the Board or such committee by means of conference telephone or similar communications equipment by means of which all persons participating in the meeting can hear each other, and participation in a meeting by such means shall constitute presence in person at such meeting.

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SECTION 3.10. Compensation. Directors shall not receive any stated salary for their services as Directors or as members of committees, except as fixed or determined by resolution of the Board. No such compensation or reimbursement shall preclude any Director from serving the Corporation in any other capacity and receiving compensation therefor.

SECTION 3.11. Interested Directors. No contract or transaction between the Corporation and one or more of its directors or officers, or between the Corporation and any other corporation, partnership, association or other organization in which one or more of its directors or officers are directors or officers or have a financial interest, shall be void or voidable solely for this reason, or solely because the director or officer is present at or participates in the meeting of the Board or committee thereof which authorizes the contract or transaction, or solely because any such director’s or officer’s vote is counted for such purpose if: (i) the material facts as to the director’s or officer’s relationship or interest and as to the contract or transaction are disclosed or are known to the Board or the committee, and the Board or committee in good faith authorizes the contract or transaction by the affirmative votes of a majority of the disinterested directors, even though the disinterested directors be less than a quorum; or (ii) the material facts as to the director’s or officer’s relationship or interest and as to the contract or transaction are disclosed or are known to the stockholders entitled to vote thereon, and the contract or transaction is specifically approved in good faith by vote of the stockholders; or (iii) the contract or transaction is fair as to the Corporation as of the time it is authorized, approved or ratified by the Board, a committee thereof or the stockholders. Common or interested directors may be counted in determining the presence of a quorum at a meeting of the Board or of a committee which authorizes the contract or transaction.

ARTICLE IV.

OFFICERS

SECTION 4.1. Officers. The officers of the Corporation shall be the President, the Secretary and a Treasurer and may include a Chairman or two Co-Chairmen, a Vice Chairman, one or more Vice Presidents (including, one or more Executive and/or Senior Vice Presidents), a Chief Financial Officer, one or more Assistant Secretaries, one or more Assistant Treasurers and such other officers as the Board may determine. Any two or more offices may be held by the same person.

SECTION 4.2. Authority and Duties. All officers shall have such authority and perform such duties in the management of the Corporation as may be provided in these Bylaws or by resolution of the Board and, to the extent not so provided, as generally pertains to their respective offices, subject to the control of the Board.

SECTION 4.3. Term of Office, Resignation and Removal.

(a) Each officer, except such officers as may be appointed in accordance with the provision of Section 4.4 or Section 4.5, shall be appointed by the Board and shall hold office for such term as may be determined by the Board. Each officer shall hold office until his or her successor has been appointed and qualified or his or her earlier death, resignation or removal in the manner hereinafter provided. The Board may require any officer to give security for the faithful performance of his or her duties.

(b) Any officer may resign at any time by giving written notice to the Board, the Chairman, the President or the Secretary. Such resignation shall take effect at the time specified in such notice or, if the time be not specified, upon receipt thereof by the Board, the Chairman, the President or the Secretary, as the

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case may be. Unless otherwise specified therein, acceptance of such resignation shall not be necessary to make it effective.

(c) All officers and agents appointed by the Board shall be subject to removal, with or without cause, at any time by the Board or by any officer upon whom such power of removal may be conferred by the Board, but such removal shall be without prejudice to the contractual rights of such officer or agent, if any, with the Corporation.

SECTION 4.4. Subordinate Officers. The Board may empower the President to appoint such other officers as the business of the Corporation may require, each of whom shall hold the office for such period, have such authority and perform such duties as are provided in these Bylaws or as the Board or President may from time to time determine.

SECTION 4.5. Vacancies. Any vacancy occurring in any office of the Corporation, for any reason, shall be filled by action of the Board. Any officer appointed by the Board to fill any such vacancy shall serve only until such time as the unexpired term of his or her predecessor expires unless reappointed by the Board, subject to his or her earlier death, resignation or removal.

SECTION 4.6. The Chairman or Co-Chairmen. The Chairman, if one shall be appointed, or Co-Chairmen, if they shall be appointed, shall have the power to call special meetings of stockholders, to call special meetings of the Board and, if present, to preside at all meetings of stockholders and all meetings of the Board. The Chairman or Co-Chairmen shall perform all duties incident to the office of Chairman and all such other duties as may from time to time be assigned to him or them by the Board or these Bylaws.

SECTION 4.7. The Vice Chairman. The Vice Chairman, if one shall be appointed, shall perform such duties as may from time to time be assigned to him by the Board or the Chairman, and in the absence or disability of the Chairman, shall perform the duties and exercise the powers of the Chairman.

SECTION 4.8. The President. The President shall have general and active management and control of the business and affairs of the Corporation, subject to the control of the Board, and shall see that all orders and resolutions of the Board are carried into effect. The President shall perform all duties incident to the office of President and all such other duties as may from time to time be assigned to him by the Board or these Bylaws.

SECTION 4.9. Vice Presidents. Vice Presidents, if any, in order of their seniority or in any other order determined by the Board, shall generally assist the President and perform such other duties as the Board or the President shall prescribe, and in the absence or disability of the President, shall perform the duties and exercise the powers of the President.

SECTION 4.10. Chief Financial Officer. The Chief Financial Officer shall perform such duties as are customary for a chief financial officer to perform and such other duties as the Board or the President shall prescribe.

SECTION 4.11. The Secretary. The Secretary shall, to the extent practicable, attend all meetings of the Board and all meetings of stockholders and shall record all votes and the minutes of all proceedings in a book to be kept for that purpose, and shall perform the same duties for any committee of the Board when so requested by such committee. He or she shall give or cause to be given notice of all meetings of stockholders and of the Board, shall perform such other duties as may be prescribed by the Board, the Chairman or the President and shall act under the supervision of the President. He or she shall keep in safe custody the seal of the Corporation and affix the same to any instrument that requires that the seal be affixed to it and which

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shall have been duly authorized for signature in the name of the Corporation and, when so affixed, the seal shall be attested by his or her signature or by the signature of the Treasurer of the Corporation (the “Treasurer”) or an Assistant Secretary or Assistant Treasurer of the Corporation. He or she shall keep in safe custody the certificate books and stockholder records and such other books and records of the Corporation as the Board, the Chairman or the President may direct and shall perform all other duties incident to the office of Secretary and such other duties as from time to time may be assigned to him by the Board, the Chairman or the President.

SECTION 4.12. Assistant \Secretaries. Assistant Secretaries of the Corporation (“Assistant Secretaries”), if any, in order of their seniority or in any other order determined by the Board, shall generally assist the Secretary and perform such other duties as the Board or the Secretary shall prescribe, and, in the absence or disability of the Secretary, shall perform the duties and exercise the powers of the Secretary.

SECTION 4.13. The Treasurer. The Treasurer shall have the care and custody of all the funds of the Corporation and shall deposit such funds in such banks or other depositories as the Board, or any officer or officers, or any officer and agent jointly, duly authorized by the Board, shall, from time to time, direct or approve. He or she shall disburse the funds of the Corporation under the direction of the Board and the President. He or she shall keep a full and accurate account of all moneys received and paid on account of the Corporation and shall render a statement of his or her accounts whenever the Board, the Chairman or the President shall so request. He or she shall perform all other necessary actions and duties in connection with the administration of the financial affairs of the Corporation and shall generally perform all of the duties usually appertaining to the office of treasurer of a corporation. When required by the Board, he or she shall give bonds for the faithful discharge of his or her duties in such sums and with such sureties as the Board shall approve.

SECTION 4.14. Assistant Treasurers. Assistant Treasurers of the Corporation (“Assistant Treasurers”), if any, in order of their seniority or in any other order determined by the Board, shall generally assist the Treasurer and perform such other duties as the Board or the Treasurer shall prescribe, and, in the absence or disability of the Treasurer, shall perform the duties and exercise the powers of the Treasurer.

ARTICLE V.

SHARES AND TRANSFERS OF SHARES

SECTION 5.1. Certificated and Uncertificated Shares. Shares shall be represented by certificates, provided that the Board may provide by resolution or resolutions that some or all of any or all classes or series of stock shall be uncertificated shares. Any such resolution shall not apply to shares represented by certificate until such certificate is surrendered to the Corporation. To the extent that shares are represented by certificates, such certificates shall be in such form or forms as shall be approved by the Board. Such certificate shall be issued in consecutive order and shall be numbered in the order of their issue. The certificate shall be signed by or in the name of the Corporation by the Chairman or Vice-Chairman of the Board or the President or any Vice President and by the Secretary, any Assistant Secretary, the Treasurer or any Assistant Treasurer certifying the number of shares owned by such holder in the Corporation. Any or all of the signatures on a certificate may be a facsimile. In the event any officer, transfer agent or registrar who has signed or whose facsimile signature has been placed upon a certificate shall have ceased to be an officer, transfer agent or register of the Corporation before such certificate is issued, such certificate may be issued by the Corporation with the same effect as if such person were such officer, transfer agent or registrar on the date of issue.

SECTION 5.2. Registered Stockholders. The Corporation shall be entitled to treat the holder of record of any shares as the holder in fact thereof and accordingly shall not be bound to recognize any equitable

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of other claim to or interest in the shares on the part of any other person whether or not it shall have express or other notice thereof except as otherwise provided by the laws of the State of Delaware.

SECTION 5.3. Transfers of Shares. Registration of transfers of shares shall be made only on the books of the Corporation upon request of the registered holder of such shares, or of his or her attorney thereunto authorized by power of attorney duly executed and filed with the Secretary, and, if the shares are represented by certificates, upon the surrender of the certificate or certificates evidencing such shares properly endorsed or accompanied by a stock power duly executed, together with such proof of the authenticity of signatures as the Corporation may reasonably require.

SECTION 5.4. Addresses of Stockholders. Each stockholder shall designate to the Secretary or transfer agents of the Corporation an address at which notices of meetings and all other corporate notices may be served or mailed to such stockholder, and, if any stockholder shall fail to so designate such an address, corporate notices may be served upon such stockholder by mail directed to the mailing address, if any, as the same appears in the stock ledger of the Corporation or at the last known mailing address of such stockholder.

SECTION 5.5. Lost, Destroyed and Mutilated Certificates. The Corporation may issue a new certificate in place of any certificate theretofore issued by it and alleged to have been mutilated, lost, stolen or destroyed, upon the surrender of the mutilated certificate or, in the case of loss, theft or destruction of the certificate, upon satisfactory proof of such loss, theft or destruction, and the Board or the transfer agents and registrars may, in their discretion, require the recordholder of the shares or his or her legal representative to give the Corporation a bond sufficient to indemnify the Corporation and said transfer agents and registrars against any claim made against it on account of the alleged loss, theft or destruction of any such certificate or the issuance of such new certificate.

SECTION 5.6. Regulations. The Board may make such other rules and regulations as it may deem expedient, not inconsistent with these Bylaws or applicable law, concerning the issue, transfer and registration of certificated or uncertificated shares.

SECTION 5.7. Fixing Date for Determination of Stockholders of Record.

(a) In order that the Corporation may determine the stockholders entitled to notice of any meeting of stockholders or any adjournment thereof, the Board may fix a record date, which record date shall not precede the date upon which the resolution fixing the record date is adopted by the Board, and which record date shall, unless otherwise required by law, not be more than 60 nor less than 10 days before the date of such meeting. If the Board so fixes a date, such date shall also be the record date for determining the stockholders entitled to vote at such meeting unless the Board determines, at the time it fixes such record date, that a later date on or before the date of the meeting shall be the date for making such determination. If no record date is fixed by the Board, the record date for determining stockholders entitled to notice of or to vote at a meeting of stockholders shall be at the close of business on the day next preceding the day on which notice is given, or, if notice is waived, at the close of business on the day next preceding the day on which the meeting is held. A determination of stockholders of record entitled to notice of or to vote at a meeting of stockholders shall apply to any adjournment of the meeting; provided, however, that the Board may fix a new record date for determination of stockholders entitled to vote at the adjourned meeting, and in such case shall also fix as the record date for stockholders entitled to notice of such adjourned meeting the same or an earlier date as that fixed for determination of stockholders entitled to vote in accordance herewith at the adjourned meeting.

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(b) In order that the Corporation may determine the stockholders entitled to receive payment of any dividend or other distribution or allotment of any rights, or entitled to exercise any rights in respect of any change, conversion or exchange of stock or for the purpose of any other lawful action, the Board may fix a record date, which shall not be more than 60 days prior to such other action. If no such record date is fixed, the record date for determining stockholders for any such purpose shall be at the close of business on the day on which the Board adopts the resolution relating thereto.

SECTION 5.8. Transfer Agents and Registrars. The Board may appoint or authorize any officer or officers to appoint one or more transfer agents and one or more registrars.

ARTICLE VI.

SEAL

SECTION 6.1. Seal. The Board may approve and adopt a corporate seal, which shall be in the form of a circle and shall bear the full name of the Corporation, the year of its incorporation and the words “Corporate Seal Delaware”.

ARTICLE VII.

FISCAL YEAR

SECTION 7.1. Fiscal Year. The fiscal year of the Corporation shall end on the thirty first day of December of each year unless changed by resolution of the Board.

ARTICLE VIII.

VOTING OF SHARES IN OTHER CORPORATIONS

SECTION 8.1. Voting of Shares in Other Corporations. Unless otherwise provided by resolution adopted by the Board, the Chairman, the Chief Executive Officer, the President or any Senior Vice President or Vice President of the Corporation may from time to time appoint an attorney or attorneys or agent or agents of the Corporation, in the name and on behalf of the Corporation, to cast the votes which the Corporation may be entitled to cast as the holder of stock or other securities in any other corporation or other entity, any of whose stock or other securities may be held by the Corporation, at meetings of the holders of the stock or other securities of such other corporation or other entity, or to consent in writing, in the name of the Corporation as such holder, to any action by such other corporation or other entity, and may instruct the person or persons so appointed as to the manner of casting such votes or giving such consents, and may execute or cause to be executed in the name and on behalf of the Corporation and under its corporate seal or otherwise, all such written proxies or other instruments as he or she may deem necessary or proper. Any of the rights set forth in this Section 8.1 which may be delegated to an attorney or agent may also be exercised directly by the Chairman, the Chief Executive Officer, the President, any Senior Vice President or Vice President of the Corporation.

ARTICLE IX.

INDEMNIFICATION AND INSURANCE

SECTION 9.1. Indemnification.

(a)    Subject to Section 9.1(c) of these Bylaws, the Corporation shall indemnify and hold harmless, to the fullest extent permitted by applicable law as it presently exists or may hereafter by amended, any

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person (a “Covered Person”) who was or is made or is threatened to be made a party or is otherwise involved in any threatened, pending or completed action, suit or proceeding, whether civil, criminal, administrative or investigative (a “Proceeding”) by reason of the fact that he, or a person for whom he or she is the legal representative, is or was a Director or officer of the Corporation or, while a Director or officer of the Corporation, is or was serving at the request of the Corporation as a Director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against all liability and loss suffered and expenses (including attorneys’ fees) reasonably incurred by such Covered Person. Notwithstanding the preceding sentence, the Corporation shall be required to indemnify a Covered Person in connection with a Proceeding (or part thereof) commenced by such Covered Person only if commencement of such Proceeding (or part thereof) by the Covered Person was authorized in the specific case by the Board.

(b) The Corporation shall to the fullest extent not prohibited by applicable law pay the expenses (including attorneys’ fees) incurred by a Covered Person in defending any proceeding in advance of its final disposition, provided,however, that, to the extent required by law, such payment of expenses in advance of the final disposition of the proceeding shall be made only upon receipt of an undertaking by the Covered Person to repay all amounts advanced if it should be ultimately determined that the Covered Person is not entitled to be indemnified under this Article IX or otherwise.

(c) To the extent that a Covered Person has been successful on the merits or otherwise in defense of any Proceeding referred to in Section 9.1 (a) of these Bylaws, or in defense of any claim, issue or matter therein, such Covered Person shall be indemnified against expenses (including attorneys’ fees) actually and reasonably incurred by such Covered Person in connection therewith.

(d) Any indemnification under Section 9.1 (a) of these Bylaws (unless ordered by a court) shall be made by the Corporation only as authorized in the specific case upon a determination that indemnification of the Covered Person is proper in the circumstances because he or she has met the applicable standard of conduct set forth in Section 145 of the General Corporation Law. Such determination shall be made, with respect to a Covered Person: (i) by a majority vote of the Directors who are not parties to such Proceeding, though less than a quorum, (ii) by a committee of such Directors designated by majority vote of such Directors, even though less than a quorum, (iii) if there are no such Directors, or if such Directors so direct, by independent legal counsel in a written opinion, or (iv) by the stockholders of the Corporation.

(e)If a claim for indemnification (following the final disposition of such proceeding) or advancement of expenses under this Article IX is not paid in full within twenty-five days after the Corporation has received a claim therefor by the Covered Person, such Covered Person shall thereupon (but not before) be entitled to file suit to recover the unpaid amount of such claim. If successful in whole or in part, such Covered Person shall be entitled to be paid the expense of prosecuting such claim to the fullest extent permitted by law. In any such action, the Corporation shall have the burden of proving that the person seeking indemnification or advancement of expenses is not entitled to the requested indemnification or advancement of expenses under applicable law.

(f)    The rights conferred on any Covered Person by this Article IX shall not be deemed exclusive of any other rights to which such Covered Person may be entitled under any law, bylaw, agreement, vote of stockholders or disinterested Directors or otherwise.

(g)    For purposes of this Article IX, references to “the Corporation” shall include, in addition to the resulting corporation, any constituent corporation (including any constituent of a constituent) absorbed in a consolidation or merger which, if its separate existence had continued, would have had power and authority to indemnify its Directors, officers, employees or agents so that any person who is or was a Director,

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officer, employee or agent of such constituent corporation, or is or was serving at the request of such constituent corporation as a Director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, shall stand in the same position under the provisions of this Article IX with respect to the resulting or surviving corporation as he or she would have with respect to such constituent corporation if its separate existence had continued.

(h)    For purposes of this Article IX, references to “other enterprises” shall include employee benefit plans; and references to “serving at the request of the Corporation” shall include any service as a Director, officer, employee or agent of the Corporation which imposes duties on, or involves service by, such Director, officer, employee or agent with respect to any employee benefit plan, its participants, or beneficiaries; and a person who acted in good faith and in a manner he or she reasonably believed to be in the interest of the participants and beneficiaries of an employee benefit plan shall be deemed to have acted in a manner “not opposed to the best interests of the Corporation” as referred to in this Article IX.

(i)The indemnification and advancement of expenses provided by, or granted pursuant to, this Article IX shall, unless otherwise provided when authorized or ratified, continue as to a person who has ceased to be a Director, officer, employee or agent and shall inure to the benefit of the heirs, executors and administrator of such a person.

(j)    Any right to indemnification or to advancement of expenses of any Covered Person arising hereunder shall not be eliminated or impaired by an amendment to or repeal of these Bylaws after the occurrence of the act or omission that is the subject of a Proceeding for which indemnification or advancement of expenses is sought.

(k)     The Corporation may, to the extent authorized from time to time by the Board, grant rights to indemnification and to the advancement of expenses to any employee or agent of the Corporation to the fullest extent of the provisions of this Article IX with respect to the indemnification and advancement of expenses of Directors and officers of the Corporation.

(l)    The Corporation’s obligation, if any, to indemnify or to advance expenses to any Covered Person who was or is serving at its request as a director, officer, employee or agent of another corporation, partnership, joint venture, trust, enterprise or nonprofit entity shall be reduced by any amount such Covered Person may collect as indemnification or advancement of expenses from such other corporation, partnership, joint venture, trust, enterprise or non-profit enterprise.

SECTION 9.2. Insurance for Indemnification. The Corporation may purchase and maintain insurance on behalf of any person who is or was a Director, officer, employee or agent of the Corporation, or is or was serving at the request of the Corporation as a Director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against any liability asserted against him and incurred by him in any such capacity, or arising out of his or her status as such, whether or not the Corporation would have the power to indemnify him against such liability under the provisions of Section 145 of the General Corporation Law.

ARTICLE X.

AMENDMENTS

SECTION 10.1. Amendments. Unless otherwise provided in the Certificate of Incorporation, any Bylaw (including these Bylaws) may be adopted, amended. altered or repealed, and new bylaws made, by the vote of the holders of 66 2/3% of the voting power of the shares entitled to vote, voting together as a single class, or by the Board.

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20

EX-10.20

Exhibit 10.20

CHENIERE ENERGY, INC.

2011 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 2011 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.

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 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 Section 4 expire and all required withholding obligations as described in Section 11 of this Grant and the provisions of the Plan have been satisfied. Except as otherwise provided in Section 6, the Participant shall have all the rights of a stockholder with respect to the Restricted Shares, including the

right to vote and the right to receive dividends or other distributions paid or made with respect to such shares. The Restricted Shares are not transferable except by will or the laws of descent and distribution or as otherwise permitted under Section 16(f) of the Plan. References to Participant, to the extent relevant in the context, shall include references to authorized transferees. Any transfer in violation of this Section 3 shall be void and of no force or effect, and shall result in the immediate forfeiture of all unvested Restricted Shares. 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 16(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 Participant ceases to serve as a Director of the Company (whether due to resignation, removal, not being re-elected by the stockholders or not standing for re-election or otherwise). 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 the forfeiture restrictions shall lapse as follows, provided that Participant remains continuously engaged as a Director of the Company, as to one hundred percent of the Restricted Shares on the earlier of (x) the day immediately prior to the date of the Company’s regular annual meeting of stockholders in the calendar year next following the calendar year in which the date of the grant occurs and (y) the one-year anniversary of the date of the grant. If Participant no longer serves as a Director of the Company, any Restricted Shares not then vested shall not vest (except as otherwise provided herein) and shall be forfeited back to the Company; provided, however, that any such Restricted Shares not then vested shall vest (i) in the event that on or within one (1) year after the effective date of a Change of Control, Participant ceases to serve as a Director of the Company (whether due to resignation, removal, not being re-elected by the stockholders or not standing for re-election or otherwise) other than due to removal for Cause, (ii) upon the death or Disability of Participant, or (iii) if Participant retires as a Director of the

Company as a result of the mandatory director retirement policy adopted by the Board, as in effect from time to time.

6.     Ownership 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 to the extent that authorized but unissued shares of Common Stock are unavailable under the Plan, 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).

7.    Reorganization of the Company. Subject to Section 15 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 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 Section 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 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.

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.

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 Right To Continued Services. Nothing in this Grant shall confer upon the Participant any right to continued service 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 service 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 Intentionally Blank]

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

CHENIERE ENERGY, INC.

By:
Name:	Ann Raden
Title:	Vice President, Human Resources & Administration

Accepted the ______ day of , 2015.

PARTICIPANT:

By:

Address:

Social Security Number:

EX-10.22

Exhibit 10.22

*** 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

Cost Impacts Associated with Delay in NTP

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-00001 DATE OF CHANGE ORDER: March 9, 2015

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

1. Per Article 6.2.A.11 of the Agreement, Parties agree to increase the Contract Price for Contractor’s increased costs to perform Work by $233,800,000 due to delay in issuance of NTP from July 1, 2014 to April 1, 2015. Pricing validity for contractual purposes is May 1, 2015.

2. The overall cost breakdown for this Change Order is detailed in Exhibit A and described 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. $***).

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 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	$	—
The Contract Price prior to this Change Order was	$	7,080,830,000
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	$	7,314,630,000

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
March 31, 2015	March 9, 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

DLE/IAC Scope 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-00002 DATE OF CHANGE ORDER: March 25, 2015

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

1. Per Article 6.2.A.11 of the Agreement, Parties agree Bechtel will change from SAC to DLE Compressor Turbine Drivers, include the Inlet Air Chilling (IAC) while removing the Inlet Air Humidification, and resize and relocate water treatment facilities.

2. The following scope changes will be incorporated from this Change Order:

a. Inlet air chilling (Stellar Chiller Package) will be added and utilized in the Nuovo Pignone PGT 2500 + G4 aero-derivative gas turbine engines for both Subproject 1 and Subproject 2.

b. Change to DLE compressor turbine drivers (GE Compressor/Turbine Package) for installed and capital spares.

c. Removal of the Inlet Air Humidification (GE Compressor/Turbine Package).

d. Resize/relocate the Water Treatment Facility from 102F01 to 105A01 (Aquatech Package).

e. Add 30” welding pipe caps on Methane Cold Boxes (Linde Package).

f. Add 30” HDPE water lines from chiller package to ISBL chiller coils.

g. Revise electrical design from 13.8kV to 34.5kV transformers.

3. Exhibit A of this Change Order depicts the changes associated with the details in Item 2 of this Change Order.

4. Article 2.5 of Attachment EE, Schedule EE-2 will be added and shall state the following:

2.5IAC Provisional Sum

The Aggregate Provisional Sum contains a Provisional Sum of *** U.S. Dollars (U.S. $***) for the inclusion of the Inlet Air Chilling package. This Work is more specifically defined as a provisional sum in Scope Change Trend S1-0016.

If the actual cost charged to Contractor for the procurement, and construction under the Agreement is less than the IAC Provisional Sum, Owner shall be entitled to a Change Order reducing the Contract Price by such difference and *** percent (***%) of such difference. If the actual cost charged to Contractor for the procurement and construction of the Work under the Agreement is greater than the IAC Provisional Sum, Contractor shall be entitled to a Change Order increasing the Contract Price by such difference, plus *** percent (***%) of such difference.

5. Bechtel and CCL agree Attachment S - “Performance Tests and Commissioning Tests” and Attachment T - “Performance Guarantee, Performance Liquidated Damages, Minimum Acceptance Criteria, and Delay Liquidated Damages” of the EPC Agreement shall be replaced with the revised versions in Exhibit B of this Change Order.

6. The overall cost breakdown for this Change Order is detailed in Exhibit C and described 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. $***).

7. The previous Aggregate Provisional Sum prior to this Change Order was Nine Hundred Fifty Million Five Hundred Sixty One Thousand Three Hundred Fifty One U.S. Dollars (U.S. $950,561,351). This Change Order will amend that value and the new value shall be One Billion, One Hundred Fifteen Million, Six Hundred eighty Seven Thousand, One Hundred Fifty One U.S. Dollars (U.S. $1,115,687,151).

8. 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 D 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)	$	233,800,000
The Contract Price prior to this Change Order was	$	7,314,630,000
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	$	7,573,977,398

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 Exhibits C and D 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/ MD 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/ Marcello Donati
Owner	Contractor
Ed Lehotsky	Marcello Donati
Name	Name
VP LNG Projects	Project Manager
Title	Title
April 7, 2015	March 25, 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

Currency and Fuel Provisional Sum Closures

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-00003 DATE OF CHANGE ORDER: May 13, 2015

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

1. The Currency Provisional Sum in Article 1.1 of Attachment EE, Schedule EE-1 of the Agreement prior to this Change Order was *** U.S Dollars (U.S. $***). The Provisional Sum is hereby decreased by $*** and the new value as amended by this Change Order shall be $***

2. Pursuant to instructions in Article 1.1 of Attachment EE, Schedule EE-1 of the Agreement, Exhibit A to this Change Order illustrates the calculation of the final currency costs in the Agreement.

3. The Fuel Provisional Sum in Article 1.2 of Attachment EE, Schedule EE-1 of the Agreement prior to this Change Order was *** U.S Dollars (U.S. $***). The Provisional Sum is hereby decreased by $*** and the new value as amended by this Change Order shall be $***.

4. Pursuant to instructions in Article 1.2 of Attachment EE, Schedule EE-1 of the Agreement, Exhibit B to this Change Order illustrates the calculation of the final fuel costs in the Agreement.

5. The Aggregate Provisional Sum specified in Article 7.1 of the Agreement prior to this Change Order was $950,561,351. The Aggregate Provisional Sum is decreased by $551,704,129 and the new value of the Aggregate Provisional Sum is $398,857,222.

6. 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. $***).

7. 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. $***)

8. Schedules C-1 and C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestones listed in Exhibit C 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, 0002, and 0004)	$	493,147,398
The Contract Price prior to this Change Order was	$	7,573,977,398
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	$	7,479,143,655

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 C 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
May 13, 2015	May 13, 2015
Date of Signing	Date of Signing

CHANGE ORDER FORM

Bridging Extension Through May 17, 2015

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-00004 DATE OF CHANGE ORDER: May 12, 2015

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

1. The last sentence of paragraph 1 of Change Order CO-00001 is amended and restated to read as follows: “Pricing validity for contractual purposes is May 17, 2015.”

2. If NTP of Corpus Christi Liquefaction Stage 1 is delayed beyond May 17, 2015, the cost impact for Stage 1 will be increased by $1,000,000 (one million USD) per Day.

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-0002)	$	493,147,398
The Contract Price prior to this Change Order was	$	7,573,977,398
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	$	7,573,977,398

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: N/A

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
May 12, 2015	May 12, 2015
Date of Signing	Date of Signing

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: July 30, 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: July 30, 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 June 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: July 30, 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 June 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: July 30, 2015

/s/ Michael J. Wortley

Michael J. Wortley
Chief Financial Officer

XML

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) - Jun. 30, 2015 - USD ($) $ in Millions	Total
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	$ 690.8
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

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Supplemental Cash Flow Information [Abstract]
Cash paid during the year for interest, net of amounts capitalized and deferred	$ 46,165	$ 49,219
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	$ 383,722	$ 286,388

XML

Long-Term Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Thousands		Jun. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		$ 14,854,794	$ 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		1,658,849	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]	1,745,939	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]	435,750	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		2,009,457	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]	2,049,646	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]	1,027,500	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		1,506,745	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]	1,493,561	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]	1,982,500	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]	1,960,000	0
2015 SPL Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		0	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]	0	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		848,091	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]	1,054,059	1,025,563
2025 CCH Holdco II 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		1,003,667	0
2025 CCH Holdco II 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	[3]	928,591	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		304,917	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]	470,706	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		398,068	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		1,705,000	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]	$ 1,705,000	$ 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 June 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.

XML

Long-Term Debt - Convertible Notes (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 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	$ 33,603,000	$ 0	$ 47,542,000	$ 0
Amortization of debt discount	7,116,000	0	13,714,000	0
Amortization of debt issuance costs	601,000	0	615,000	0
Total interest expense related to the Convertible Notes	$ 41,320,000	$ 0	$ 61,871,000	$ 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, Conversion Price	$ 93.64		$ 93.64
Convertible Debt								808,800,000
Debt Instrument, Convertible, Carrying Amount of Equity Component	$ 195,700,000		$ 195,700,000				$ 191,500,000	$ 191,200,000
Debt Instrument, Interest Rate, Effective Percentage	9.10%		9.10%				9.20%
Debt Instrument, Convertible, Remaining Discount Amortization Period			5 years 11 months 1 day
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, 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 8 months
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 1			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 closing			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	Jun. 30, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 13,799,113	$ 9,246,753
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(381,285)	(350,497)
Property, plant and equipment, net	13,590,497	9,083,373
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,466,559	2,269,429
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	11,495,832	7,155,046
LNG site and related costs, net [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	9,391	9,395
Fixed assets and other [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(33,227)	(30,169)
Property, plant and equipment, net	208,616	163,380
Computer and office equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	10,145	7,464
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	16,620	10,733
Computer software [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	64,320	46,882
Leasehold improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	38,047	36,067
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	59,087	55,522
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 53,624	$ 36,881

XML

Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2015

Debt Instrument [Line Items]

Schedule of Long-term Debt Instruments

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

	Interest	June 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)	—			—
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)	400,000			400,000
2015 CCH Credit Facility (4)	(5)	1,705,000			—
Total long-term debt		15,348,120			9,989,969
Long-term debt premium (discount)
2016 SPLNG Senior Notes		(6,651		)	(8,998		)
2021 SPL Senior Notes		9,457			10,177
2023 SPL Senior Notes		6,745			7,088
2021 Cheniere Convertible Unsecured Notes		(180,862		)	(189,717		)
2045 Cheniere Convertible Senior Notes		(320,083		)	—
CTPL Term Loan		(1,932		)	(2,435		)
Total long-term debt, net		$	14,854,794		$	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) 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.

(4) 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.

(5) 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.

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:

	June 30, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 SPLNG Senior Notes, net of discount (1)	$	1,658,849	$	1,745,939	$	1,656,502	$	1,718,621
2020 SPLNG Senior Notes (1)	420,000		435,750		420,000		428,400
2021 SPL Senior Notes, net of premium (1)	2,009,457		2,049,646		2,010,177		1,985,050
2022 SPL Senior Notes (1)	1,000,000		1,027,500		1,000,000		1,020,000
2023 SPL Senior Notes, net of premium (1)	1,506,745		1,493,561		1,507,089		1,476,947
2024 SPL Senior Notes (1)	2,000,000		1,982,500		2,000,000		1,970,000
2025 SPL Senior Notes (1)	2,000,000		1,960,000		—		—
2015 SPL Credit Facilities (2)	—		—		—		—
2021 Cheniere Convertible Unsecured Notes, net of discount (3)	848,091		1,054,059		814,751		1,025,563
2025 CCH Holdco II Convertible Senior Notes (3)	1,003,667		928,591		—		—
2045 Cheniere Convertible Senior Notes, net of discount (4)	304,917		470,706		—		—
CTPL Term Loan, net of discount (2)	398,068		400,000		397,565		400,000
2015 CCH Credit Facility (2)	1,705,000		1,705,000		—		—

(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 June 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 June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Interest per contractual rate	$	33,603	$	—	$	47,542	$	—
Amortization of debt discount	7,116		—		13,714		—
Amortization of debt issuance costs	601		—		615		—
Total interest expense related to the Convertible Notes	$	41,320	$	—	$	61,871	$	—

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Share-Based Compensation (Details) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015 USD ($) shares	Jun. 30, 2014 USD ($)	Jun. 30, 2015 USD ($) Installment_vestings annual_performance_periods shares	Jun. 30, 2014 USD ($) 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 | $	$ 50,300	$ 26,100	$ 66,378	$ 62,013
Share-based compensation capitalized during period | $	18,400	2,500	20,300	4,300
Share-based compensation, unrecognized compensation | $	462,200		$ 462,200
Share-based compensation, unrecognized compensation, period for recognition			2 years 6 months 1 day
Proceeds from exercise of stock options | $	900	2,600	$ 1,914	6,265
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			5,500	5,600
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%

XML

Accrued Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Accrued Liabilities [Abstract]
Interest expense and related debt fees	$ 235,996	$ 112,858
Employee-related costs	78,908	6,425
LNG liquefaction costs	229,375	22,014
LNG terminal costs	6,477	1,077
Other accrued liabilities	15,076	26,755
Total accrued liabilities	$ 565,832	$ 169,129

XML

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Thousands		Jun. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Non-current derivative assets		$ 21,363	$ 11,744
Derivative liabilities		(23,937)	(23,247)
Commodity Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		914	881
Total derivative liabilities		(816)	(320)
Derivative asset (liability), net		98	561
Commodity Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		488	295
Commodity Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		426	586
Commodity Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(718)	(53)
Commodity Derivatives [Member] | Other non-current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other non-current liabilities		(98)	(267)
Natural Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	181	219
Total derivative liabilities	[1]	(496)	0
Derivative asset (liability), net	[1]	(315)	219
Natural Gas Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets	[1]	181	219
Derivative, Collateral, Right to Reclaim Cash		6,300	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]	(496)	0
Natural Gas Derivatives [Member] | Other non-current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other non-current liabilities	[1]	0	0
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		733	662
Total derivative liabilities		(320)	(320)
Derivative asset (liability), net		413	342
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		307	76
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		426	586
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(222)	(53)
Liquefaction Supply Derivatives [Member] | Other non-current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other non-current liabilities		(98)	(267)
Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		20,937	11,158
Total derivative liabilities		(23,774)	(23,194)
Derivative asset (liability), net		(2,837)	(12,036)
Interest Rate Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		0	0
Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		20,937	11,158
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(23,219)	(23,194)
Interest Rate Derivatives [Member] | Other non-current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other non-current liabilities		(555)	0
Sabine Pass Liquefaction [Member] | SPL Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		0	11,158
Total derivative liabilities		(8,172)	(23,194)
Derivative asset (liability), net		(8,172)	(12,036)
Sabine Pass Liquefaction [Member] | SPL Interest Rate Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		0	0
Sabine Pass Liquefaction [Member] | SPL Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		0	11,158
Sabine Pass Liquefaction [Member] | SPL Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(7,617)	(23,194)
Sabine Pass Liquefaction [Member] | SPL Interest Rate Derivatives [Member] | Other non-current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other non-current liabilities		(555)	0
Cheniere Corpus Christi Holdings, LLC [Member] | CCH Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		20,937	0
Total derivative liabilities		(15,602)	0
Derivative asset (liability), net		5,335	0
Cheniere Corpus Christi Holdings, LLC [Member] | CCH Interest Rate Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		0	0
Cheniere Corpus Christi Holdings, LLC [Member] | CCH Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		20,937	0
Cheniere Corpus Christi Holdings, LLC [Member] | CCH Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(15,602)	0
Cheniere Corpus Christi Holdings, LLC [Member] | CCH Interest Rate Derivatives [Member] | Other non-current liabilities [Member]
Derivatives, Fair Value [Line Items]
Other non-current liabilities		$ 0	$ 0

[1] Does not include collateral of $6.3 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of June 30, 2015 and December 31, 2014, respectively.

XML

Commitments and Contingencies (Details) shares in Millions		3 Months Ended
	Feb. 01, 2013 shares	Jun. 30, 2014 item	Jun. 30, 2015 shares	Jan. 31, 2013 shares
Commitments and Contingencies [Line Items]
Loss Contingency, New Claims Filed, Number | item		4
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

Long-Term Debt - Other (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Apr. 30, 2014	May. 31, 2013
Debt Instrument [Line Items]
Interest Costs Incurred	$ 241,200,000	$ 140,400,000	$ 421,900,000	$ 269,000,000
Interest Costs Capitalized	155,700,000	$ 96,600,000	$ 276,800,000	$ 184,900,000
CTPL Term Loan [Member]
Debt Instrument [Line Items]
Basis Spread on Variable Rate			3.25%
CTPL Term Loan [Member] | Cheniere Creole Trail Pipeline LP [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity	400,000,000		$ 400,000,000				$ 400,000,000
SPL LC Agreement [Member] | Sabine Pass Liquefaction [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity						$ 325,000,000
Basis Spread on Variable Rate			2.00%
Letters of Credit Outstanding, Amount	72,900,000		$ 72,900,000		$ 9,500,000
Draws under LC Agreement	$ 0		$ 0		$ 0
SPL LC Agreement [Member] | Sabine Pass Liquefaction [Member] | Unissued Portion [Member]
Debt Instrument [Line Items]
Commitment Fee Percentage			0.75%
SPL LC Agreement [Member] | Sabine Pass Liquefaction [Member] | Portion issued and not drawn [Member]
Debt Instrument [Line Items]
Commitment Fee Percentage			2.50%

XML

Property, Plant and Equipment

6 Months Ended

Jun. 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):

	June 30,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	2,466,559		$	2,269,429
LNG terminal construction-in-process	11,495,832			7,155,046
LNG site and related costs, net	9,391			9,395
Accumulated depreciation	(381,285		)	(350,497		)
Total LNG terminal costs, net	13,590,497			9,083,373
Fixed assets and other
Computer and office equipment	10,145			7,464
Furniture and fixtures	16,620			10,733
Computer software	64,320			46,882
Leasehold improvements	38,047			36,067
Land	59,087			55,522
Other	53,624			36,881
Accumulated depreciation	(33,227		)	(30,169		)
Total fixed assets and other, net	208,616			163,380
Property, plant and equipment, net	$	13,799,113		$	9,246,753

XML

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) - USD ($)		6 Months Ended
		Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 15,348,120,000	$ 9,989,969,000
Total long-term debt, net		$ 14,854,794,000	9,806,084,000
2016 SPLNG Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.50%
Long-term Debt, Gross		$ 1,665,500,000	1,665,500,000
Debt Instrument, Unamortized Discount		$ (6,651,000)	(8,998,000)
2020 SPLNG Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Long-term Debt, Gross		$ 420,000,000	420,000,000
2021 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Long-term Debt, Gross		$ 2,000,000,000	2,000,000,000
Debt Instrument, Unamortized Premium		$ 9,457,000	10,177,000
2022 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.25%
Long-term Debt, Gross		$ 1,000,000,000	1,000,000,000
2023 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Long-term Debt, Gross		$ 1,500,000,000	1,500,000,000
Debt Instrument, Unamortized Premium		$ 6,745,000	7,088,000
2024 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.75%
Long-term Debt, Gross		$ 2,000,000,000	2,000,000,000
2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Long-term Debt, Gross		$ 2,000,000,000	0
2015 SPL Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1],[2]	$ 0	0
Debt Instrument, Description of Variable Rate Basis		LIBOR
2015 SPL Credit Facilities [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.30%
2015 SPL Credit Facilities [Member] | London Interbank Offered Rate (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		$ 1,028,953,000	1,004,469,000
Debt Instrument, Unamortized Discount		(180,862,000)	(189,717,000)
2025 CCH Holdco II Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 1,003,667,000	0
2045 Cheniere Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.25%
Long-term Debt, Gross		$ 625,000,000	0
Debt Instrument, Unamortized Discount		(320,083,000)	0
CTPL Term Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[3]	400,000,000	400,000,000
Debt Instrument, Unamortized Discount		$ (1,932,000)	(2,435,000)
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	[4],[5]	$ 1,705,000,000	$ 0
Debt Instrument, Description of Variable Rate Basis		LIBOR
2015 CCH Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Construction [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.25%
2015 CCH Credit Facility [Member] | London Interbank Offered Rate (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%

[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%.

[3] 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.

[4] 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.

[5] 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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Restricted Cash - SPLNG Senior Notes Debt Service Reserve (Details)	6 Months Ended
	Jun. 30, 2015 USD ($) Rate	Dec. 31, 2014 USD ($)
Restricted Cash Items [Line Items]
Current restricted cash	$ 684,073,000	$ 481,737,000
Non-current restricted cash	$ 739,145,000	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%
Sabine Pass LNG, LP [Member] | Sabine Pass LNG Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Fixed Charge, Coverage Ratio | Rate	2
Sabine Pass LNG, LP [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%
Sabine Pass LNG, LP [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%
Sabine Pass LNG, LP [Member] | Senior Notes Interest Payments [Member]
Restricted Cash Items [Line Items]
Current restricted cash	$ 15,000,000	15,000,000
Sabine Pass LNG, LP [Member] | Debt Service Reserve Fund [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash	$ 76,100,000	$ 76,100,000

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Supplemental Cash Flow Information (Tables)

6 Months Ended

Jun. 30, 2015

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

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

	Six Months Ended June 30,
	2015		2014
Cash paid during the year for interest, net of amounts capitalized and deferred	$	46,165	$	49,219
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	383,722		286,388

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Long-Term Debt - Senior Notes (Details) - USD ($)	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Mar. 31, 2015
Sabine Pass LNG, LP [Member]
Debt Instrument [Line Items]
Partners' Capital Account, Distributions	$ 199,600,000	$ 173,000,000
2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.625%
2025 SPL Senior Notes [Member] | Sabine Pass Liquefaction [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	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2013
Restricted Cash Items [Line Items]
Current restricted cash	$ 481,737,000	$ 684,073,000
Non-current restricted cash	550,811,000	$ 739,145,000
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%
Sabine Pass Liquefaction [Member] | 2013 SPL Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				$ 5,900,000,000
Sabine Pass Liquefaction [Member] | 2015 SPL Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 4,600,000,000
Sabine Pass Liquefaction [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%
Sabine Pass Liquefaction [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%
Sabine Pass Liquefaction [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
Sabine Pass Liquefaction [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%
Sabine Pass Liquefaction [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%
Sabine Pass Liquefaction [Member] | Payment of Liabilities [Member]
Restricted Cash Items [Line Items]
Current restricted cash	$ 155,800,000	$ 340,500,000
Sabine Pass Liquefaction [Member] | Construction Activities [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash	$ 457,100,000	$ 656,000,000

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Restricted Cash - CTPL Reserve (Details)	Jun. 30, 2015 USD ($) mi	Dec. 31, 2014 USD ($)	May. 31, 2013 USD ($)
Restricted Cash Items [Line Items]
Current restricted cash	$ 684,073,000	$ 481,737,000
Non-current restricted cash	$ 739,145,000	550,811,000
Creole Trail Pipeline LP [Member] | Creole Trail Pipeline [Member]
Restricted Cash Items [Line Items]
Length of Natural Gas Pipeline, in miles | mi	94
Creole Trail Pipeline LP [Member] | CTPL Term Loan [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 400,000,000		$ 400,000,000
Creole Trail Pipeline LP [Member] | Payment of Liabilities [Member]
Restricted Cash Items [Line Items]
Current restricted cash	19,000,000	24,900,000
Creole Trail Pipeline LP [Member] | Construction And Interest Payments [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash	$ 0	$ 11,300,000

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Restricted Cash

6 Months Ended

Jun. 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 both June 30, 2015 and December 31, 2014, we classified $15.0 million as current restricted cash for the payment of current interest due. As of both June 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, 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 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 (the “Additional 2023 SPL Senior Notes” and collectively with the Initial 2023 SPL Senior Notes, the “2023 SPL Senior Notes”) in an aggregate principal amount of $0.5 billion, before premium. 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 June 30, 2015 and December 31, 2014, we classified $340.5 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 $656.0 million 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 June 30, 2015 and December 31, 2014, we classified $19.0 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 such funds may only be used for modifications of the 94-mile Creole Trail Pipeline, which interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines, 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”), which 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, and the Corpus Christi Pipeline, 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”) and approximately $3.1 billion linked to the second stage (“Stage 2”) of the CCL Project, which 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 June 30, 2015, we classified $92.0 million and zero as current restricted cash and non-current restricted cash, respectively, held by CCH.

Other Restricted Cash

As of June 30, 2015 and December 31, 2014, $196.0 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 June 30, 2015 and December 31, 2014, $21.6 million and $35.9 million, respectively, had been classified as current restricted cash, and as of June 30, 2015 and December 31, 2014, $7.0 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.

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Restricted Cash - CCH Reserve and Other (Details) $ in Thousands	Jun. 30, 2015 USD ($) mi in	May. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
Restricted Cash Items [Line Items]
Current restricted cash	$ 684,073		$ 481,737
Non-current restricted cash	739,145		550,811
Subsidiary Cash [Member]
Restricted Cash Items [Line Items]
Current restricted cash	196,000		250,100
Other Contractual Restrictions [Member]
Restricted Cash Items [Line Items]
Current restricted cash	21,600		35,900
Non-current restricted cash	$ 7,000		$ 6,300
Cheniere Corpus Christi Holdings, LLC [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
Cheniere Corpus Christi Holdings, LLC [Member] | 2015 CCH Credit Facility [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 11,500,000
Cheniere Corpus Christi Holdings, LLC [Member] | 2015 CCH Credit Facility [Member] | Stage 1 [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		8,400,000
Cheniere Corpus Christi Holdings, LLC [Member] | 2015 CCH Credit Facility [Member] | Stage 2 [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 3,100,000
Cheniere Corpus Christi Holdings, LLC [Member] | Construction And Interest Payments [Member]
Restricted Cash Items [Line Items]
Current restricted cash	$ 92,000
Non-current restricted cash	$ 0

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Derivative Instruments - Derivative Net Presentation on Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Natural Gas Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		$ 223
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets		(4)
Derivative Assets (Liabilities), at Fair Value, Net		219
Natural Gas Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	$ (595)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	280
Derivative Assets (Liabilities), at Fair Value, Net	(315)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	733	662
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	733	662
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(320)	(320)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	(320)	(320)
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	(8,172)	(23,194)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	(8,172)	$ (23,194)
CCH Interest Rate Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	20,937
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	0
Derivative Assets (Liabilities), at Fair Value, Net	20,937
CCH Interest Rate Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(15,602)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (15,602)

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Business Segment Information (Details) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015 USD ($)	Jun. 30, 2014 USD ($)	Jun. 30, 2015 USD ($) item	Jun. 30, 2014 USD ($)	Dec. 31, 2014 USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | item				2
Revenues (losses) from external customers	[1]	$ 68,025	$ 67,645	$ 136,394	$ 135,195
Intersegment revenues (losses)	[2]	0	0	0	0
Depreciation expense		20,154	17,298	37,923	32,773
Loss from operations		(95,580)	(62,135)	(156,578)	(109,747)
Interest expense, net		(85,486)	(43,789)	(145,098)	(84,059)
Loss before income taxes and non-controlling interest	[3]	(142,309)	(280,626)	(477,475)	(402,879)
Share-based compensation		68,665	28,619	86,655	66,317
Goodwill		76,819	76,819	76,819	76,819	$ 76,819
Total assets		17,759,502	11,859,295	17,759,502	11,859,295	$ 12,573,683
Expenditures for additions to long-lived assets		3,966,465	816,444	4,586,205	1,502,447
LNG terminal business [Member]
Segment Reporting Information [Line Items]
Revenues (losses) from external customers	[1]	68,532	66,841	136,112	133,260
Intersegment revenues (losses)	[2]	491	734	594	1,506
Depreciation expense		16,071	14,810	31,012	29,216
Loss from operations		(17,767)	(20,607)	(42,856)	(28,123)
Interest expense, net		(59,465)	(43,895)	(102,310)	(84,268)
Loss before income taxes and non-controlling interest	[3]	(33,403)	(234,123)	(311,058)	(311,477)
Share-based compensation		25,778	3,512	28,917	6,562
Goodwill		76,819	76,819	76,819	76,819
Total assets		15,964,158	10,861,606	15,964,158	10,861,606
Expenditures for additions to long-lived assets		3,944,191	809,658	4,534,436	1,469,437
LNG and natural gas marketing business [Member]
Segment Reporting Information [Line Items]
Revenues (losses) from external customers	[1]	(706)	324	(44)	982
Intersegment revenues (losses)	[2]	6,354	1,900	13,371	4,074
Depreciation expense		244	109	444	261
Loss from operations		(26,367)	(14,907)	(31,550)	(26,501)
Interest expense, net		0	0	0	0
Loss before income taxes and non-controlling interest	[3]	(26,816)	(15,189)	(32,206)	(26,916)
Share-based compensation		6,052	2,421	10,087	8,931
Goodwill		0	0	0	0
Total assets		567,541	63,020	567,541	63,020
Expenditures for additions to long-lived assets		1,400	471	2,114	785
Corporate and other [Member]
Segment Reporting Information [Line Items]
Revenues (losses) from external customers	[1],[4]	199	480	326	953
Intersegment revenues (losses)	[2],[4]	(6,845)	(2,634)	(13,965)	(5,580)
Depreciation expense	[4]	3,839	2,379	6,467	3,296
Loss from operations	[4]	(51,446)	(26,621)	(82,172)	(55,123)
Interest expense, net	[4]	(26,021)	106	(42,788)	209
Loss before income taxes and non-controlling interest	[3],[4]	(82,090)	(31,314)	(134,211)	(64,486)
Share-based compensation	[4]	36,835	22,686	47,651	50,824
Goodwill	[4]	0	0	0	0
Total assets	[4]	1,227,803	934,669	1,227,803	934,669
Expenditures for additions to long-lived assets	[4]	$ 20,874	$ 6,315	$ 49,655	$ 32,225
Cheniere Energy Partners, LP [Member]
Segment Reporting Information [Line Items]
General Partner Ownership Percentage				100.00%
Cheniere Energy Partners LP Holdings, LLC [Member]
Segment Reporting Information [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent		80.10%		80.10%		80.10%
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy Partners, LP [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.

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Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 1,470,207	$ 1,747,583
Restricted cash	684,073	481,737
Accounts and interest receivable	6,746	4,419
LNG inventory	13,954	4,294
Other current assets	88,382	20,844
Total current assets	2,263,362	2,258,877
Non-current restricted cash	739,145	550,811
Property, plant and equipment, net	13,799,113	9,246,753
Debt issuance costs, net	637,301	242,323
Non-current derivative assets	21,363	11,744
Goodwill	76,819	76,819
Other non-current assets	222,399	186,356
Total assets	17,759,502	12,573,683
Current liabilities
Accounts payable	23,799	13,426
Accrued liabilities	565,832	169,129
Deferred revenue	26,671	26,655
Derivative liabilities	23,937	23,247
Other current liabilities	600	18
Total current liabilities	640,839	232,475
Long-term debt, net	14,854,794	9,806,084
Non-current deferred revenue	11,500	13,500
Other non-current liabilities	$ 37,013	$ 20,107
Commitments and contingencies (see Footnote 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 June 30, 2015 and December 31, 2014; Issued and outstanding: 236.6 and 236.7 million shares at June 30, 2015 and December 31, 2014, respectively	711	712
Treasury stock: 10.7 million shares and 10.6 million shares at June 30, 2015 and December 31, 2014, respectively, at cost	(298,926)	(292,752)
Additional paid-in-capital	3,014,483	2,776,702
Accumulated deficit	(3,035,043)	(2,648,839)
Total stockholders’ deficit	(318,775)	(164,177)
Non-controlling interest	2,534,131	2,665,694
Total equity	2,215,356	2,501,517
Total liabilities and equity	$ 17,759,502	$ 12,573,683

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Long-Term Debt - Credit Facilities (Details) - USD ($)		1 Months Ended		3 Months Ended		6 Months Ended
		Mar. 31, 2015	May. 31, 2014	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	May. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Line of Credit Facility [Line Items]
Long-term Debt, Outstanding Borrowings				$ 15,348,120,000		$ 15,348,120,000			$ 9,989,969,000
Losses on Extinguishment of Debt				7,281,000	$ 114,335,000	96,273,000	$ 114,335,000
2015 SPL Credit Facilities [Member]
Line of Credit Facility [Line Items]
Long-term Debt, Outstanding Borrowings	[1],[2]			0		$ 0			0
Debt Instrument, Description of Variable Rate Basis						LIBOR
2015 SPL Credit Facilities [Member] | Sabine Pass Liquefaction [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				4,600,000,000		$ 4,600,000,000
Line of Credit Facility, Remaining Borrowing Capacity				4,600,000,000		4,600,000,000
Long-term Debt, Outstanding Borrowings	[3],[4]			0		0
Debt Instrument, Fee Amount				$ 89,900,000		$ 89,900,000
Line Of Credit Facility Insurance Premium Percentage Of Drawn Amount						0.45%
Line Of Credit Facility, Unused Capacity, Commitment Fee Percentage Of Margin On Undrawn Commitment						40.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage						0.70%
Line of Credit Facility, Amortization Period						18 years
Debt Instrument Hedging Requirement Period						90 days
2015 SPL Credit Facilities [Member] | Sabine Pass Liquefaction [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] | Sabine Pass Liquefaction [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity										$ 5,900,000,000
Long-term Debt, Outstanding Borrowings	[3],[4]								0
Line of Credit Facility, Decrease, Net		$ 1,800,000,000	$ 2,100,000,000
Losses on Extinguishment of Debt				$ 7,300,000		$ 96,300,000
2015 CCH Credit Facility [Member]
Line of Credit Facility [Line Items]
Long-term Debt, Outstanding Borrowings	[3],[4]			1,705,000,000		$ 1,705,000,000			$ 0
Debt Instrument, Description of Variable Rate Basis						LIBOR
2015 CCH Credit Facility [Member] | Cheniere Corpus Christi Holdings, LLC [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				$ 6,700,000,000		$ 6,700,000,000
Debt Instrument, Fee Amount								289,800,000
Line of Credit Facility, Amortization Period						19 years
Ratio of Indebtedness to Net Capital				155.00%		155.00%
Line of Credit Facility, Commitment Fee Percentage						40.00%
Debt Instrument Hedging Requirement Period						90 days
2015 CCH Credit Facility [Member] | Cheniere Corpus Christi Holdings, LLC [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives				65.00%		65.00%
2015 CCH Credit Facility [Member] | Cheniere Corpus Christi Holdings, LLC [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] | Cheniere Corpus Christi Holdings, LLC [Member] | Stage 2 [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								$ 3,100,000,000

[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%.

[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	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities
Net loss	$ (477,646)	$ (403,055)
Adjustments to reconcile net loss to net cash used in operating activities:
Loss on early extinguishment of debt	96,273	114,335
Depreciation expense	37,923	32,773
Amortization of debt issuance costs and discount	24,900	5,639
Share-based compensation	66,378	62,013
Non-cash LNG inventory write-downs	17,366	14,978
Total losses on derivatives, net	80,198	94,859
Net cash used for settlement of derivative instruments	(88,934)	(17,437)
Other	29,133	(1,826)
Changes in restricted cash for certain operating activities	(55,410)	82,927
Changes in operating assets and liabilities:
Accounts and interest receivable	(2,396)	461
Accounts payable and accrued liabilities	42,101	22,856
LNG inventory	(27,026)	(14,376)
Deferred revenue	(1,985)	(1,955)
Other, net	(35,830)	(3,533)
Net cash used in operating activities	(294,955)	(11,341)
Cash flows from investing activities
Property, plant and equipment, net	(4,294,814)	(1,352,400)
Use of restricted cash for the acquisition of property, plant and equipment	4,183,620	1,303,011
Other	(101,836)	(5,894)
Net cash used in investing activities	(213,030)	(55,283)
Cash flows from financing activities
Proceeds from issuances of long-term debt	5,205,000	2,584,500
Investment in restricted cash	(4,518,880)	(2,282,903)
Debt issuance and deferred financing costs	(411,149)	(85,367)
Distributions and dividends to non-controlling interest	(40,121)	(39,644)
Repayments of long-term debt	0	(177,000)
Payments related to tax withholdings for share-based compensation	(6,174)	(9,218)
Proceeds from exercise of stock options	1,914	6,265
Other	19	(964)
Net cash provided by (used in) financing activities	230,609	(4,331)
Net decrease in cash and cash equivalents	(277,376)	(70,955)
Cash and cash equivalents—beginning of period	1,747,583	960,842
Cash and cash equivalents—end of period	$ 1,470,207	$ 889,887

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Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 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	$ (315)	$ 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	(315)	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	413	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	(27)	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	440	342
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	(8,172)	(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	(8,172)	(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	5,335	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	5,335	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)

6 Months Ended

Jun. 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):

	June 30,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	2,466,559		$	2,269,429
LNG terminal construction-in-process	11,495,832			7,155,046
LNG site and related costs, net	9,391			9,395
Accumulated depreciation	(381,285		)	(350,497		)
Total LNG terminal costs, net	13,590,497			9,083,373
Fixed assets and other
Computer and office equipment	10,145			7,464
Furniture and fixtures	16,620			10,733
Computer software	64,320			46,882
Leasehold improvements	38,047			36,067
Land	59,087			55,522
Other	53,624			36,881
Accumulated depreciation	(33,227		)	(30,169		)
Total fixed assets and other, net	208,616			163,380
Property, plant and equipment, net	$	13,799,113		$	9,246,753

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Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Liquefaction Supply Derivatives [Member] - USD ($)	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net Fair Value Asset	$ 413,000	$ 342,000
Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net Fair Value Asset	$ 440,000	$ 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	$ 0.020

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Accrued Liabilities (Tables)

6 Months Ended

Jun. 30, 2015

Accrued Liabilities [Abstract]

Schedule of Accrued Liabilities

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

	June 30,		December 31,
	2015		2014
Interest expense and related debt fees	$	235,996	$	112,858
Employee-related costs	78,908		6,425
LNG liquefaction costs	229,375		22,014
LNG terminal costs	6,477		1,077
Other accrued liabilities	15,076		26,755
Total accrued liabilities	$	565,832	$	169,129

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Basis of Presentation

6 Months Ended

Jun. 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 six months ended June 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	Jun. 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	236,600	236,745
Common Stock, Shares, Outstanding	236,600	236,745
Treasury Stock, Shares	10,690	10,596

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Commitments and Contingencies

6 Months Ended

Jun. 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 Incentive 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.

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Document and Entity Information Document - shares	6 Months Ended
	Jun. 30, 2015	Jul. 21, 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	Jun. 30, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		236,573,788

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Business Segment Information

6 Months Ended

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

	Segments
	LNG Terminal			LNG & Natural Gas Marketing			Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended June 30, 2015
Revenues (losses) from external customers (2)	$	68,532		$	(706	)	$	199		$	68,025
Intersegment revenues (losses) (3)	491			6,354			(6,845		)	—
Depreciation expense	16,071			244			3,839			20,154
Loss from operations	(17,767		)	(26,367		)	(51,446		)	(95,580		)
Interest expense, net	(59,465		)	—			(26,021		)	(85,486		)
Loss before income taxes and non-controlling interest (4)	(33,403		)	(26,816		)	(82,090		)	(142,309		)
Share-based compensation	25,778			6,052			36,835			68,665
Goodwill	76,819			—			—			76,819
Total assets	15,964,158			567,541			1,227,803			17,759,502
Expenditures for additions to long-lived assets	3,944,191			1,400			20,874			3,966,465
As of or for the Three Months Ended June 30, 2014
Revenues from external customers (2)	$	66,841		$	324		$	480		$	67,645
Intersegment revenues (losses) (3)	734			1,900			(2,634		)	—
Depreciation expense	14,810			109			2,379			17,298
Loss from operations	(20,607		)	(14,907		)	(26,621		)	(62,135		)
Interest expense, net	(43,895		)	—			106			(43,789		)
Loss before income taxes and non-controlling interest (4)	(234,123		)	(15,189		)	(31,314		)	(280,626		)
Share-based compensation	3,512			2,421			22,686			28,619
Goodwill	76,819			—			—			76,819
Total assets	10,861,606			63,020			934,669			11,859,295
Expenditures for additions to long-lived assets	809,658			471			6,315			816,444
For the Six Months Ended June 30, 2015
Revenues (losses) from external customers (2)	$	136,112		$	(44	)	$	326		$	136,394
Intersegment revenues (losses) (3)	594			13,371			(13,965		)	—
Depreciation expense	31,012			444			6,467			37,923
Loss from operations	(42,856		)	(31,550		)	(82,172		)	(156,578		)
Interest expense, net	(102,310		)	—			(42,788		)	(145,098		)
Loss before income taxes and non-controlling interest (4)	(311,058		)	(32,206		)	(134,211		)	(477,475		)
Share-based compensation	28,917			10,087			47,651			86,655
Expenditures for additions to long-lived assets	4,534,436			2,114			49,655			4,586,205
For the Six Months Ended June 30, 2014
Revenues from external customers (2)	$	133,260		$	982		$	953		$	135,195
Intersegment revenues (losses) (3)	1,506			4,074			(5,580		)	—
Depreciation expense	29,216			261			3,296			32,773
Loss from operations	(28,123		)	(26,501		)	(55,123		)	(109,747		)
Interest expense, net	(84,268		)	—			209			(84,059		)
Loss before income taxes and non-controlling interest (4)	(311,477		)	(26,916		)	(64,486		)	(402,879		)
Share-based compensation	6,562			8,931			50,824			66,317
Expenditures for additions to long-lived assets	1,469,437			785			32,225			1,502,447

(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		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues
LNG terminal revenues		$ 67,905	$ 66,841	$ 135,486	$ 133,260
Marketing and trading revenues (losses)		(706)	324	(44)	981
Other		826	480	952	954
Total revenues	[1]	68,025	67,645	136,394	135,195
Operating costs and expenses
General and administrative expense		107,856	67,720	165,873	141,528
Operating and maintenance expense		18,877	29,409	56,030	43,096
Depreciation expense		20,154	17,298	37,923	32,773
Development expense		16,609	15,263	32,705	27,375
Other		109	90	441	170
Total operating costs and expenses		163,605	129,780	292,972	244,942
Loss from operations		(95,580)	(62,135)	(156,578)	(109,747)
Other income (expense)
Interest expense, net		(85,486)	(43,789)	(145,098)	(84,059)
Loss on early extinguishment of debt		(7,281)	(114,335)	(96,273)	(114,335)
Derivative gain (loss), net		45,755	(60,178)	(80,181)	(94,859)
Other income (expense)		283	(189)	655	121
Total other expense		(46,729)	(218,491)	(320,897)	(293,132)
Loss before income taxes and non-controlling interest	[2]	(142,309)	(280,626)	(477,475)	(402,879)
Income tax benefit (provision)		507	(84)	(171)	(176)
Net loss		(141,802)	(280,710)	(477,646)	(403,055)
Less: net loss attributable to non-controlling interest		(23,307)	(78,782)	(91,442)	(103,317)
Net loss attributable to common stockholders		$ (118,495)	$ (201,928)	$ (386,204)	$ (299,738)
Net loss per share attributable to common stockholders—basic and diluted		$ (0.52)	$ (0.90)	$ (1.71)	$ (1.34)
Weighted average number of common shares outstanding—basic and diluted		226,481	223,602	226,405	223,406

[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

6 Months Ended

Jun. 30, 2015

Accrued Liabilities [Abstract]

Accrued Liabilities

ACCRUED LIABILITIES

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

	June 30,		December 31,
	2015		2014
Interest expense and related debt fees	$	235,996	$	112,858
Employee-related costs	78,908		6,425
LNG liquefaction costs	229,375		22,014
LNG terminal costs	6,477		1,077
Other accrued liabilities	15,076		26,755
Total accrued liabilities	$	565,832	$	169,129

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Non-Controlling Interest

6 Months Ended

Jun. 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 June 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)

6 Months Ended

Jun. 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 June 30, 2015 and December 31, 2014, which are classified as other current assets, non-current derivative assets, derivative liabilities and other non-current liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	June 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 (liability)	$	—	$	(315	)	$	—	$	(315	)	$	—	$	219		$	—	$	219
Liquefaction Supply Derivatives asset (liability)	—		(27		)	440		413			—		—			342		342
SPL Interest Rate Derivatives liability	—		(8,172		)	—		(8,172		)	—		(12,036		)	—		(12,036		)
CCH Interest Rate Derivatives asset	—		5,335			—		5,335			—		—			—		—

Fair Value Inputs, Assets, Quantitative Information

The following table (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of June 30, 2015:

	Net Fair Value Asset	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Liquefaction Supply Derivatives	$440	Income Approach	Basis Spread	$ (0.350) - $0.020

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 June 30, 2015
Natural Gas Derivatives	$	(595	)	$	280		$	(315	)
Liquefaction Supply Derivatives	733			—			733
Liquefaction Supply Derivatives	(320		)	—			(320		)
SPL Interest Rate Derivatives	(8,172		)	—			(8,172		)
CCH Interest Rate Derivatives	20,937			—			20,937
CCH Interest Rate Derivatives	(15,602		)	—			(15,602		)
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:

	June 30, 2015									December 31, 2014
	Natural Gas Derivatives (1)			Liquefaction Supply Derivatives			Total			Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			Total
Balance Sheet Location
Other current assets	$	181		$	307		$	488		$	219	$	76		$	295
Non-current derivative assets	—			426			426			—		586			586
Total derivative assets	181			733			914			219		662			881
Derivative liabilities	(496		)	(222		)	(718		)	—		(53		)	(53		)
Other non-current liabilities	—			(98		)	(98		)	—		(267		)	(267		)
Total derivative liabilities	(496		)	(320		)	(816		)	—		(320		)	(320		)
Derivative asset (liability), net	$	(315	)	$	413		$	98		$	219	$	342		$	561

(1) Does not include collateral of $6.3 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of June 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 six months ended June 30, 2015 and 2014:

		Three Months Ended June 30,						Six Months Ended June 30,
	Statement of Operations Location	2015			2014			2015			2014
Natural Gas Derivatives gain (loss)	Marketing and trading revenues (losses)	$	67		$	21		$	(98	)	$	370
Natural Gas Derivatives gain (loss)	Derivative gain (loss), net	(294		)	(56		)	460			(258		)
Natural Gas Derivatives gain	Operating and maintenance expense	—			—			—			44
Liquefaction Supply Derivatives gain (1)	Operating and maintenance expense	81			—			81			—

(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 June 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	$690.8 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 of our interest rate derivatives:

	June 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
Other current assets	$	—		$	—		$	—		$	—		$	—	$	—
Non-current derivative assets	—			20,937			20,937			11,158			—		11,158
Total derivative assets	—			20,937			20,937			11,158			—		11,158
Derivative liabilities	(7,617		)	(15,602		)	(23,219		)	(23,194		)	—		(23,194		)
Other non-current liabilities	(555		)	—			(555		)	—			—		—
Total derivative liabilities	(8,172		)	(15,602		)	(23,774		)	(23,194		)	—		(23,194		)
Derivative asset (liability), net	$	(8,172	)	$	5,335		$	(2,837	)	$	(12,036	)	$	—	$	(12,036	)

Derivative Instruments, Gain (Loss)

The following table (in thousands) shows the changes in the fair value and settlements of our 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 six months ended June 30, 2015 and 2014:

	Three Months Ended June 30,					Six Months Ended June 30,
	2015		2014			2015			2014
SPL Interest Rate Derivatives gain (loss)	$	1,469	$	(60,122	)	$	(35,669	)	$	(94,601	)
CCH Interest Rate Derivatives gain (loss)	44,580		—			(44,972		)	—

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Supplemental Cash Flow Information

6 Months Ended

Jun. 30, 2015

Supplemental Cash Flow Information [Abstract]

Supplemental Cash Flow Information

SUPPLEMENTAL CASH FLOW INFORMATION

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

	Six Months Ended June 30,
	2015		2014
Cash paid during the year for interest, net of amounts capitalized and deferred	$	46,165	$	49,219
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	383,722		286,388

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Share-Based Compensation

6 Months Ended

Jun. 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 2011 Plan. As of June 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 the Board of Directors approved the 2014-2018 LTIP, which is a sub-plan of the Company’s 2015 Long-Term Cash Incentive Plan. 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 awarded generally 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 issued 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 records 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. During the three and six months ended June 30, 2015, we granted 5.5 million and 5.6 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 six months ended June 30, 2014.

For the three months ended June 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $50.3 million and $26.1 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $18.4 million and $2.5 million, respectively. For the six months ended June 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $66.4 million and $62.0 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $20.3 million and $4.3 million, respectively. We did not recognize any cumulative adjustments in our compensation expense for the six months ended June 30, 2015 and 2014.

The total unrecognized compensation cost at June 30, 2015 relating to non-vested share-based compensation arrangements was $462.2 million, which is expected to be recognized over a weighted average period of 2.5 years.

We received $0.9 million and $2.6 million in the three months ended June 30, 2015 and 2014, respectively, and $1.9 million and $6.3 million in the six months ended June 30, 2015 and 2014, respectively, of proceeds from the exercise of stock options.

During the three and six months ended June 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 six months ended June 30, 2015.

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Long-Term Debt

6 Months Ended

Jun. 30, 2015

Debt Disclosure [Abstract]

Long-term Debt

LONG-TERM DEBT

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

	Interest	June 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)	—			—
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)	400,000			400,000
2015 CCH Credit Facility (4)	(5)	1,705,000			—
Total long-term debt		15,348,120			9,989,969
Long-term debt premium (discount)
2016 SPLNG Senior Notes		(6,651		)	(8,998		)
2021 SPL Senior Notes		9,457			10,177
2023 SPL Senior Notes		6,745			7,088
2021 Cheniere Convertible Unsecured Notes		(180,862		)	(189,717		)
2045 Cheniere Convertible Senior Notes		(320,083		)	—
CTPL Term Loan		(1,932		)	(2,435		)
Total long-term debt, net		$	14,854,794		$	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) 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.

(4) 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.

(5) 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.

For the three months ended June 30, 2015 and 2014, we incurred $241.2 million and $140.4 million of total interest cost, respectively, of which we capitalized and deferred $155.7 million and $96.6 million, respectively, of interest cost, including amortization of debt issuance costs, primarily related to the construction of the first four Trains of the SPL Project. For the six months ended June 30, 2015 and 2014, we incurred $421.9 million and $269.0 million of total interest cost, respectively, of which we capitalized and deferred $276.8 million and $184.9 million, respectively, of interest cost, 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 six months ended June 30, 2015 and 2014, SPLNG made distributions of $199.6 million and $173.0 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 periods.

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 June 30, 2015, SPL had $4.6 billion of available commitments and no outstanding borrowings under the 2015 SPL Credit Facilities.

SPL incurred $89.9 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 either: (1) a rate per annum equal to 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.

Under the terms of the 2015 SPL Credit Facilities, within 90 days of the closing date, 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 $7.3 million and $96.3 million for the three and six months ended June 30, 2015, respectively.

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 June 30, 2015 and December 31, 2014, the carrying value of the equity component was $195.7 million and $191.5 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 June 30, 2015 and December 31, 2014, respectively, and the remaining period over which the debt discount will be amortized was 5.9 years as of June 30, 2015. As of June 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 Convertible 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 Cheniere CCH HoldCo I.

At our 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 our 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 June 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 June 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 June 30, 2015, and the remaining period over which the debt discount will be amortized was 29.7 years. As of June 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 June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Interest per contractual rate	$	33,603	$	—	$	47,542	$	—
Amortization of debt discount	7,116		—		13,714		—
Amortization of debt issuance costs	601		—		615		—
Total interest expense related to the Convertible Notes	$	41,320	$	—	$	61,871	$	—

CTPL Term Loan

As of June 30, 2015, CTPL had borrowed the full amount of $400.0 million available under the CTPL Term Loan. The CTPL Term Loan matures in 2017 when the full amount of the outstanding principal obligations must be repaid.  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 June 30, 2015, CCH had $6.7 billion of available commitments and $1.7 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 1.55x.

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, within 90 days of the closing date, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt.

SPL LC Agreement

In April 2014, SPL entered into a $325.0 million senior letter of credit and reimbursement agreement (the “SPL LC Agreement”) that it uses for the issuance of letters of credit for certain working capital requirements related to the SPL Project. SPL pays (1) a commitment fee in an amount equal to an annual rate of 0.75% of an amount equal to the unissued portion of letters of credit available pursuant to the SPL LC Agreement and (2) a letter of credit fee equal to an annual rate of 2.5% of the undrawn portion of all letters of credit issued under the SPL LC Agreement. If draws are made upon any letters of credit issued under the SPL LC Agreement, the amount of the draw will be deemed a loan issued to SPL.  SPL is required to pay the full amount of this loan on or prior to the business day immediately succeeding the deemed issuance of the loan.  These loans accrue interest at a rate of 2.0% plus the base rate as defined in the SPL LC Agreement. As of June 30, 2015 and December 31, 2014, SPL had issued letters of credit in an aggregate amount of $72.9 million and $9.5 million, respectively, and as of both June 30, 2015 and December 31, 2014, no draws had been made upon any letters of credit issued under the SPL LC Agreement.

Fair Value Disclosures

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

	June 30, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 SPLNG Senior Notes, net of discount (1)	$	1,658,849	$	1,745,939	$	1,656,502	$	1,718,621
2020 SPLNG Senior Notes (1)	420,000		435,750		420,000		428,400
2021 SPL Senior Notes, net of premium (1)	2,009,457		2,049,646		2,010,177		1,985,050
2022 SPL Senior Notes (1)	1,000,000		1,027,500		1,000,000		1,020,000
2023 SPL Senior Notes, net of premium (1)	1,506,745		1,493,561		1,507,089		1,476,947
2024 SPL Senior Notes (1)	2,000,000		1,982,500		2,000,000		1,970,000
2025 SPL Senior Notes (1)	2,000,000		1,960,000		—		—
2015 SPL Credit Facilities (2)	—		—		—		—
2021 Cheniere Convertible Unsecured Notes, net of discount (3)	848,091		1,054,059		814,751		1,025,563
2025 CCH Holdco II Convertible Senior Notes (3)	1,003,667		928,591		—		—
2045 Cheniere Convertible Senior Notes, net of discount (4)	304,917		470,706		—		—
CTPL Term Loan, net of discount (2)	398,068		400,000		397,565		400,000
2015 CCH Credit Facility (2)	1,705,000		1,705,000		—		—

(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 June 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

6 Months Ended

Jun. 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 (expense) of $0.5 million and $(0.1) million for the three months ended June 30, 2015 and 2014, respectively, and a net expense of $0.2 million for each of the six months ended June 30, 2015 and 2014 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

6 Months Ended

Jun. 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 reconciles basic and diluted weighted average common shares outstanding for the three and six months ended June 30, 2015 and 2014 (in thousands, except for loss per share):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Weighted average common shares outstanding:
Basic	226,481			223,602			226,405			223,406
Dilutive common stock options (1)	—			—			—			—
Diluted	226,481			223,602			226,405			223,406
Basic and diluted net loss per share attributable to common stockholders	$	(0.52	)	$	(0.90	)	$	(1.71	)	$	(1.34	)

(1) Stock options and unvested stock of 10.1 million shares and 14.5 million shares for the three months ended June 30, 2015 and 2014, respectively, and 10.1 million shares and 14.4 million shares for the six months ended June 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, 38.6 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 six months ended June 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		6 Months Ended
	May. 31, 2015 USD ($)	Mar. 31, 2015 USD ($)	May. 31, 2014 USD ($)	Jun. 30, 2015 USD ($) MMBTU	Jun. 30, 2014 USD ($)	Jun. 30, 2015 USD ($) MMBTU	Jun. 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				2,162.8		2,162.8
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount | MMBTU				1,250.3		1,250.3
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
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
Sabine Pass Liquefaction [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
Sabine Pass Liquefaction [Member] | SPL Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Loss, Net		$ 34,700,000	$ 9,300,000

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Net Loss Per Share Attributable to Common Stockholders (Details) - $ / shares shares in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Weighted Average Number of Shares Outstanding, Basic		226,481	223,602	226,405	223,406
Dilutive common stock options	[1]	0	0	0	0
Weighted Average Number of Shares Outstanding, Diluted		226,481	223,602	226,405	223,406
Basic and diluted net loss per share attributable to common stockholders		$ (0.52)	$ (0.90)	$ (1.71)	$ (1.34)
Stock options, warrants 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		10,100	14,500	10,100	14,400
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		38,600		38,600

[1] Stock options and unvested stock of 10.1 million shares and 14.5 million shares for the three months ended June 30, 2015 and 2014, respectively, and 10.1 million shares and 14.4 million shares for the six months ended June 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, 38.6 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 six months ended June 30, 2015 because the computation of diluted net loss per share utilizing the “if-converted” method would be anti-dilutive.

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Basis of Presentation (Policies)

6 Months Ended

Jun. 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)

6 Months Ended

Jun. 30, 2015

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The following table reconciles basic and diluted weighted average common shares outstanding for the three and six months ended June 30, 2015 and 2014 (in thousands, except for loss per share):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Weighted average common shares outstanding:
Basic	226,481			223,602			226,405			223,406
Dilutive common stock options (1)	—			—			—			—
Diluted	226,481			223,602			226,405			223,406
Basic and diluted net loss per share attributable to common stockholders	$	(0.52	)	$	(0.90	)	$	(1.71	)	$	(1.34	)

(1) Stock options and unvested stock of 10.1 million shares and 14.5 million shares for the three months ended June 30, 2015 and 2014, respectively, and 10.1 million shares and 14.4 million shares for the six months ended June 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, 38.6 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 six months ended June 30, 2015 because the computation of diluted net loss per share utilizing the “if-converted” method would be anti-dilutive.

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Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Income Tax Disclosure [Abstract]
Income tax benefit (expense)	$ 507	$ (84)	$ (171)	$ (176)

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Non-Controlling Interest (Details) - $ / shares	1 Months Ended	6 Months Ended
	Nov. 30, 2014	Jun. 30, 2015	Dec. 31, 2014
Cheniere Energy Partners, LP [Member]
Noncontrolling Interest [Line Items]
General Partner Ownership Percentage		100.00%
Cheniere Energy Partners LP Holdings, LLC [Member]
Noncontrolling Interest [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent		80.10%	80.10%
Cheniere Energy Partners LP Holdings, LLC [Member]
Noncontrolling Interest [Line Items]
Issuance of Stock, Shares	10,100,000.0
Shares Issued, Price Per Share	$ 22.76
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy Partners, LP [Member]
Noncontrolling Interest [Line Items]
Limited Partner ownership percentage		55.90%
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy Partners, LP [Member] | Common Units [Member]
Noncontrolling Interest [Line Items]
Partners Capital Account, Units, Units Held		12,000,000
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy Partners, LP [Member] | Capital Unit, Class B [Member]
Noncontrolling Interest [Line Items]
Partners Capital Account, Units, Units Held		45,300,000
Cheniere Energy Partners LP Holdings, LLC [Member] | Cheniere Energy Partners, LP [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 - 6 months ended Jun. 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		57	0
Exercise of stock options	1,914	$ 0	$ 0	1,914	0	0
Issuances of restricted stock, shares		16	0
Issuances of restricted stock	0	$ 0	$ 0	0	0	0
Forfeitures of restricted stock, shares		138	14
Forfeitures of restricted stock	0	$ (1)	$ 0	1	0	0
Share-based compensation	37,411	$ 0	$ 0	37,411	0	0
Shares repurchased related to share-based compensation, shares		80	80
Shares repurchased related to share-based compensation	(6,174)	$ 0	$ (6,174)	0	0	0
Excess tax benefit from share-based compensation	129	0	0	129	0	0
Equity portion of issuance of convertible notes, net	198,326	0	0	198,326	0	0
Loss attributable to non-controlling interest	(91,442)	0	0	0	0	(91,442)
Distributions to non-controlling interest	(40,121)	0	0	0	0	(40,121)
Net loss	$ (386,204)	$ 0	$ 0	0	(386,204)	0
Common Stock, Shares, Outstanding, End of Period at Jun. 30, 2015	236,600	236,600
Treasury Stock, Shares, End of Period at Jun. 30, 2015	10,690		10,690
Stockholders' Equity, End of Period at Jun. 30, 2015	$ 2,215,356	$ 711	$ (298,926)	$ 3,014,483	$ (3,035,043)	$ 2,534,131

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Derivative Instruments

6 Months Ended

Jun. 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”);

• 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”); 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”).

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 June 30, 2015 and December 31, 2014, which are classified as other current assets, non-current derivative assets, derivative liabilities and other non-current liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	June 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 (liability)	$	—	$	(315	)	$	—	$	(315	)	$	—	$	219		$	—	$	219
Liquefaction Supply Derivatives asset (liability)	—		(27		)	440		413			—		—			342		342
SPL Interest Rate Derivatives liability	—		(8,172		)	—		(8,172		)	—		(12,036		)	—		(12,036		)
CCH Interest Rate Derivatives asset	—		5,335			—		5,335			—		—			—		—

The estimated fair values of our Natural Gas Derivatives and the economic hedges related to the Liquefaction Supply 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 our 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, 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 June 30, 2015 and December 31, 2014, the majority of the Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow. Therefore, our internal fair value models were based on a market price that equated 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.

There were no transfers into or out of Level 3 Liquefaction Supply Derivatives for the three and six months ended June 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 (in thousands, except natural gas basis spread) includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of June 30, 2015:

	Net Fair Value Asset	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Liquefaction Supply Derivatives	$440	Income Approach	Basis Spread	$ (0.350) - $0.020

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.  

Commodity Derivatives

We recognize all commodity derivative instruments, including our Natural Gas Derivatives and the Liquefaction Supply 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:

	June 30, 2015									December 31, 2014
	Natural Gas Derivatives (1)			Liquefaction Supply Derivatives			Total			Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			Total
Balance Sheet Location
Other current assets	$	181		$	307		$	488		$	219	$	76		$	295
Non-current derivative assets	—			426			426			—		586			586
Total derivative assets	181			733			914			219		662			881
Derivative liabilities	(496		)	(222		)	(718		)	—		(53		)	(53		)
Other non-current liabilities	—			(98		)	(98		)	—		(267		)	(267		)
Total derivative liabilities	(496		)	(320		)	(816		)	—		(320		)	(320		)
Derivative asset (liability), net	$	(315	)	$	413		$	98		$	219	$	342		$	561

(1) Does not include collateral of $6.3 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of June 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 six months ended June 30, 2015 and 2014:

		Three Months Ended June 30,						Six Months Ended June 30,
	Statement of Operations Location	2015			2014			2015			2014
Natural Gas Derivatives gain (loss)	Marketing and trading revenues (losses)	$	67		$	21		$	(98	)	$	370
Natural Gas Derivatives gain (loss)	Derivative gain (loss), net	(294		)	(56		)	460			(258		)
Natural Gas Derivatives gain	Operating and maintenance expense	—			—			—			44
Liquefaction Supply Derivatives gain (1)	Operating and maintenance expense	81			—			81			—

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

The use of Commodity Derivatives exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our Commodity Derivatives are in an asset position.

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 June 30, 2015, SPL has secured up to approximately 2,162.8 million MMBtu 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 1,250.3 million MMBtu, which were recorded as derivatives due to minimum purchase requirements.

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 its interest rate derivatives related to the 2013 SPL Credit Facilities 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 June 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	$690.8 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 of our interest rate derivatives:

	June 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
Other current assets	$	—		$	—		$	—		$	—		$	—	$	—
Non-current derivative assets	—			20,937			20,937			11,158			—		11,158
Total derivative assets	—			20,937			20,937			11,158			—		11,158
Derivative liabilities	(7,617		)	(15,602		)	(23,219		)	(23,194		)	—		(23,194		)
Other non-current liabilities	(555		)	—			(555		)	—			—		—
Total derivative liabilities	(8,172		)	(15,602		)	(23,774		)	(23,194		)	—		(23,194		)
Derivative asset (liability), net	$	(8,172	)	$	5,335		$	(2,837	)	$	(12,036	)	$	—	$	(12,036	)

The following table (in thousands) shows the changes in the fair value and settlements of our 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 six months ended June 30, 2015 and 2014:

	Three Months Ended June 30,					Six Months Ended June 30,
	2015		2014			2015			2014
SPL Interest Rate Derivatives gain (loss)	$	1,469	$	(60,122	)	$	(35,669	)	$	(94,601	)
CCH Interest Rate Derivatives gain (loss)	44,580		—			(44,972		)	—

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 June 30, 2015
Natural Gas Derivatives	$	(595	)	$	280		$	(315	)
Liquefaction Supply Derivatives	733			—			733
Liquefaction Supply Derivatives	(320		)	—			(320		)
SPL Interest Rate Derivatives	(8,172		)	—			(8,172		)
CCH Interest Rate Derivatives	20,937			—			20,937
CCH Interest Rate Derivatives	(15,602		)	—			(15,602		)
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)

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

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

	Segments
	LNG Terminal			LNG & Natural Gas Marketing			Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended June 30, 2015
Revenues (losses) from external customers (2)	$	68,532		$	(706	)	$	199		$	68,025
Intersegment revenues (losses) (3)	491			6,354			(6,845		)	—
Depreciation expense	16,071			244			3,839			20,154
Loss from operations	(17,767		)	(26,367		)	(51,446		)	(95,580		)
Interest expense, net	(59,465		)	—			(26,021		)	(85,486		)
Loss before income taxes and non-controlling interest (4)	(33,403		)	(26,816		)	(82,090		)	(142,309		)
Share-based compensation	25,778			6,052			36,835			68,665
Goodwill	76,819			—			—			76,819
Total assets	15,964,158			567,541			1,227,803			17,759,502
Expenditures for additions to long-lived assets	3,944,191			1,400			20,874			3,966,465
As of or for the Three Months Ended June 30, 2014
Revenues from external customers (2)	$	66,841		$	324		$	480		$	67,645
Intersegment revenues (losses) (3)	734			1,900			(2,634		)	—
Depreciation expense	14,810			109			2,379			17,298
Loss from operations	(20,607		)	(14,907		)	(26,621		)	(62,135		)
Interest expense, net	(43,895		)	—			106			(43,789		)
Loss before income taxes and non-controlling interest (4)	(234,123		)	(15,189		)	(31,314		)	(280,626		)
Share-based compensation	3,512			2,421			22,686			28,619
Goodwill	76,819			—			—			76,819
Total assets	10,861,606			63,020			934,669			11,859,295
Expenditures for additions to long-lived assets	809,658			471			6,315			816,444
For the Six Months Ended June 30, 2015
Revenues (losses) from external customers (2)	$	136,112		$	(44	)	$	326		$	136,394
Intersegment revenues (losses) (3)	594			13,371			(13,965		)	—
Depreciation expense	31,012			444			6,467			37,923
Loss from operations	(42,856		)	(31,550		)	(82,172		)	(156,578		)
Interest expense, net	(102,310		)	—			(42,788		)	(145,098		)
Loss before income taxes and non-controlling interest (4)	(311,058		)	(32,206		)	(134,211		)	(477,475		)
Share-based compensation	28,917			10,087			47,651			86,655
Expenditures for additions to long-lived assets	4,534,436			2,114			49,655			4,586,205
For the Six Months Ended June 30, 2014
Revenues from external customers (2)	$	133,260		$	982		$	953		$	135,195
Intersegment revenues (losses) (3)	1,506			4,074			(5,580		)	—
Depreciation expense	29,216			261			3,296			32,773
Loss from operations	(28,123		)	(26,501		)	(55,123		)	(109,747		)
Interest expense, net	(84,268		)	—			209			(84,059		)
Loss before income taxes and non-controlling interest (4)	(311,477		)	(26,916		)	(64,486		)	(402,879		)
Share-based compensation	6,562			8,931			50,824			66,317
Expenditures for additions to long-lived assets	1,469,437			785			32,225			1,502,447

(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		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Natural Gas Derivatives [Member] | Marketing and trading revenues (losses)
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		$ 67,000	$ 21,000	$ (98,000)	$ 370,000
Natural Gas Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		(294,000)	(56,000)	460,000	(258,000)
Natural Gas Derivatives [Member] | Operating and maintenance expense
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		0	0	0	44,000
Liquefaction Supply Derivatives [Member] | Operating and maintenance expense
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	[1]	81,000	0	81,000	0
Settlements during the period		0	0	0	0
SPL Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		1,469,000	(60,122,000)	(35,669,000)	(94,601,000)
CCH Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		$ 44,580,000	$ 0	$ (44,972,000)	$ 0

[1] There were no physical settlements during the reporting period.

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Recent Accounting Standards

6 Months Ended

Jun. 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, 2016, including interim periods within that reporting period, with earlier adoption not 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 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. 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.