10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

  For the quarterly period ended September 30, 2013

OR

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

  For the transition period from                 to             

Commission File No. 001-16383

CHENIERE ENERGY, INC.

(Exact name of registrant as specified in its charter)

Delaware	95-4352386
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
700 Milam Street, Suite 800
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  o

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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No  o

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 S	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  o  No  x

238,896,010 shares of the registrant’s Common Stock, $0.003 par value, were issued and outstanding as of October 16, 2013. 

CHENIERE ENERGY, INC.

TABLE OF CONTENTS

Part I. Financial Information
Item 1.	Consolidated Financial Statements	1
	Consolidated Balance Sheets	1
	Consolidated Statements of Operations	2
	Consolidated Statements of Comprehensive Loss	3
	Consolidated Statements of Stockholders' Equity	4
	Consolidated Statements of Cash Flows	5
	Notes to Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	24
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	39
Item 4.	Controls and Procedures	40
Part II. Other Information
Item 1.	Legal Proceedings	40
Item 5.	Other Information	41
Item 6.	Exhibits	42

i

PART I.        FINANCIAL INFORMATION

ITEM 1.    CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands, except share data)

	September 30,			December 31,
	2013			2012
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	374,164		$	201,711
Restricted cash and cash equivalents	577,945			520,263
Accounts and interest receivable	26,079			3,486
LNG inventory	14,401			7,045
Prepaid expenses and other	16,471			16,058
Total current assets	1,009,060			748,563
Non-current restricted cash and cash equivalents	828,858			272,924
Property, plant and equipment, net	5,705,567			3,282,305
Debt issuance costs, net	340,856			220,949
Non-current derivative assets	64,309			—
Goodwill	76,819			76,819
Intangible LNG assets	4,366			4,356
Advance under long-term contracts	12,528			—
Other	83,490			33,169
Total assets	$	8,125,853		$	4,639,085
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Accounts payable	$	6,345		$	74,360
Accrued liabilities	172,015			58,737
Deferred revenue	26,585			26,540
Other	8,292			126
Total current liabilities	213,237			159,763
Long-term debt, net of discount	5,574,195			2,167,113
Non-current derivative liabilities	—			26,424
Long-term deferred revenue	18,500			21,500
Other long-term liabilities	3,572			2,680
Commitments and contingencies
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 both September 30, 2013 and December 31, 2012
Issued and outstanding: 238.8 million shares and 223.4 million shares at September 30, 2013 and December 31, 2012, respectively	718			671
Treasury stock: 7.8 million shares and 4.7 million shares at September 30, 2013 and December 31, 2012, respectively, at cost	(128,252		)	(39,115		)
Additional paid-in-capital	2,382,424			2,168,781
Accumulated deficit	(1,965,677		)	(1,592,985		)
Accumulated other comprehensive loss	—			(27,351		)
Total stockholders' equity	289,213			510,001
Non-controlling interest	2,027,136			1,751,604
Total equity	2,316,349			2,261,605
Total liabilities and equity	$	8,125,853		$	4,639,085

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

1

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

(unaudited)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Revenues
LNG terminal revenues	$	66,735		$	65,939		$	199,222		$	199,269
Marketing and trading revenues	590			(292		)	441			(1,641		)
Other	385			351			1,130			1,171
Total revenues	67,710			65,998			200,793			198,799
Operating costs and expenses
LNG terminal operating expense	30,098			14,056			76,425			36,606
LNG terminal development expense	11,046			11,721			50,214			54,629
Depreciation, depletion and amortization	15,246			15,233			45,533			47,001
General and administrative expense	57,096			79,427			277,971			120,236
Other	100			78			258			244
Total operating costs and expenses	113,586			120,515			450,401			258,716
Loss from operations	(45,876		)	(54,517		)	(249,608		)	(59,917		)
Other income (expense)
Interest expense, net	(52,528		)	(45,504		)	(134,806		)	(159,719		)
Loss on early extinguishment of debt	—			—			(80,510		)	(15,098		)
Derivative gain (loss), net	(22,335		)	287			55,706			(288		)
Other income (expense)	65			(12,081		)	954			(11,500		)
Total other expense	(74,798		)	(57,298		)	(158,656		)	(186,605		)
Loss before income taxes and non-controlling interest	(120,674		)	(111,815		)	(408,264		)	(246,522		)
Income tax provision	(1,809		)	(61		)	(2,751		)	(211		)
Net loss	(122,483		)	(111,876		)	(411,015		)	(246,733		)
Non-controlling interest	21,659			2,875			38,323			8,277
Net loss attributable to common stockholders	$	(100,824	)	$	(109,001	)	$	(372,692	)	$	(238,456	)
Net loss per share attributable to common stockholders - basic and diluted	$	(0.46	)	$	(0.52	)	$	(1.71	)	$	(1.40	)
Weighted average number of common shares outstanding - basic and diluted	220,734			208,712			217,940			170,414

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

2

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(in thousands)

(unaudited)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Net loss	$	(122,483	)	$	(111,876	)	(411,015		)	$	(246,733	)
Other comprehensive income (loss)
Interest rate cash flow hedges
Loss on settlements retained in other comprehensive income	—			—			(30		)	—
Change in fair value of interest rate cash flow hedges	—			(29,676		)	21,297			(29,676		)
Losses reclassified into earnings as a result of discontinuance of cash flow hedge accounting	—			—			5,973			—
Foreign currency translation	135			153			111			137
Total other comprehensive income (loss)	135			(29,523		)	27,351			(29,539		)
Comprehensive loss	(122,348		)	(141,399		)	(383,664		)	(276,272		)
Comprehensive loss attributable to non-controlling interest	21,659			2,875			36,291			8,277
Comprehensive loss attributable to common stockholders	$	(100,689	)	$	(138,524	)	$	(347,373	)	$	(267,995	)

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

3

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(in thousands)

(unaudited)

	Total Stockholders' (Deficit) Equity
	Common Stock					Treasury Stock				Additional Paid-in Capital			Accumulated Deficit			Accumulated Other Comprehensive Loss			Non- controlling Interest			Total (Deficit) Equity
	Shares		Amount			Shares	Amount
Balance—December 31, 2012	223,397		$	671		4,727	$	(39,115	)	$	2,168,781		$	(1,592,985	)	$	(27,351	)	$	1,751,604		$	2,261,605
Issuances of stock	23		—			—	—			274			—			—			—			274
Issuances of restricted stock	18,531		56			—	—			(56		)	—			—			—			—
Forfeitures of restricted stock	(129	)	—			70	—			—			—			—			—			—
Stock-based compensation	—		—			—	—			211,346			—			—			—			211,346
Shares repurchased related to tax withholdings for stock-based compensation	(3,013	)	(9		)	3,013	(89,137		)	9			—			—			—			(89,137		)
Tax benefit from stock-based compensation	—		—			—	—			2,070			—			—			—			2,070
Foreign currency translation	—		—			—	—			—			—			111			—			111
Interest rate cash flow hedges	—		—							—						25,207			2,032			27,239
Loss attributable to non-controlling interest	—		—			—	—			—			—			—			(38,323		)	(38,323		)
Sale of common units to non-controlling interest	—		—			—	—			—			—			2,033			361,869			363,902
Distribution to non-controlling interest	—		—			—	—			—			—			—			(50,046		)	(50,046		)
Net loss	—		—			—	—			—			(372,692		)	—			—			(372,692		)
Balance—September 30, 2013	238,809		$	718		7,810	$	(128,252	)	$	2,382,424		$	(1,965,677	)	$	—		$	2,027,136		$	2,316,349

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

4

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Nine Months Ended
	September 30,
	2013			2012
Cash flows from operating activities
Net loss attributable to common stockholders	$	(372,692	)	$	(238,456	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization	45,533			47,001
Loss on early extinguishment of debt	80,510			15,095
Amortization of debt issuance and discount costs	8,590			18,073
Non-cash compensation	202,785			53,961
Non-cash LNG inventory write-downs	27,851			9,763
Non-cash derivative (gain) loss, net	(55,053		)	698
Net loss attributable to non-controlling interest	(38,323		)	(8,277		)
Use of restricted cash and cash equivalents for certain operating activities	113,626			24,139
Crest royalty	—			(13,384		)
Other	(2,622		)	(2,715		)
Changes in operating assets and liabilities:
Accounts and interest receivable	(21,514		)	(23,871		)
Accounts payable and accrued liabilities	55,043			19,413
LNG inventory, net	(29,071		)	(6,308		)
Deferred revenue	(2,955		)	(3,104		)
Prepaid expenses and other	(34,011		)	2,993
Net cash used in operating activities	(22,303		)	(104,979		)
Cash flows from investing activities
LNG terminal and pipeline costs, net	(2,448,690		)	(871,167		)
Use of restricted cash and cash equivalents for the acquisition of property, plant and equipment	2,466,613			1,352,656
Investment in Cheniere Partners	(11,122		)	(534,940		)
Other	(26,471		)	(21,596		)
Net cash provided by (used in) investing activities	(19,670		)	(75,047		)
Cash flows from financing activities
Proceeds from Sabine Pass Liquefaction Senior Notes, net	3,012,500			—
Proceeds from CTPL Credit Facility, net	391,978			—
Proceeds from sale of common units by Cheniere Partners	364,775			205,174
Proceeds from 2013 Liquefaction Credit Facilities	100,000			—
Proceeds from sale of common stock, net	274			1,200,717
Proceeds from sales of Class B units by Cheniere Partners	(3		)	887,563
Investment in restricted cash and cash equivalents	(3,182,735		)	(1,425,209		)
Repurchases and prepayments of debt	—			(776,514		)
Debt issuance and deferred financing costs	(235,250		)	(210,828		)
Proceeds from (repayment of) 2012 Liquefaction Credit Facility	(100,000		)	100,000
Distributions to non-controlling interest	(50,046		)	(24,628		)
Payments related to tax withholdings for stock-based compensation	(89,137		)	(20,414		)
Excess tax benefit from stock-based compensation	2,070			—
Net cash used in financing activities	214,426			(64,139		)
Net increase (decrease) in cash and cash equivalents	172,453			(244,165		)
Cash and cash equivalents—beginning of period	201,711			459,160
Cash and cash equivalents—end of period	$	374,164		$	214,995

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

5

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—ORGANIZATION AND NATURE OF OPERATIONS

Cheniere Energy, Inc., a Delaware corporation, is a Houston-based energy company primarily engaged in liquefied natural gas ("LNG") related businesses. We own and operate the Sabine Pass liquefied natural gas ("LNG") terminal in Louisiana through our 57.9% ownership interest in and management agreements with Cheniere Energy Partners, L.P. ("Cheniere Partners") (NYSE MKT: CQP), which is a publicly traded partnership that we created in 2007.  The Sabine Pass LNG terminal is located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast. The Sabine Pass LNG terminal has regasification facilities owned by Cheniere Partners' wholly owned subsidiary, Sabine Pass LNG, L.P. ("Sabine Pass LNG") that includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with capacity of up to 265,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d.

Cheniere Partners is developing natural gas liquefaction facilities (the "Liquefaction Project") at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, Sabine Pass Liquefaction, LLC ("Sabine Pass Liquefaction"). We plan to construct up to six Trains, which are in various stages of development. Each Train is expected to have nominal production capacity of approximately 4.5 million tonnes per annum ("mtpa") of LNG.

In May 2013, we sold our ownership interests in Cheniere Creole Trail Pipeline, L.P. ("CTPL") and Cheniere Pipeline GP Interests, LLC (collectively, the "Creole Trail Pipeline Business") to Cheniere Partners for $480.0 million and were reimbursed $13.9 million for certain expenditures incurred prior to the closing date.  Concurrent with the Creole Trail Pipeline Business sale closing, we acquired 12.0 million Class B units from Cheniere Partners for aggregate consideration of $180.0 million pursuant to a unit purchase agreement between Cheniere Partners and Cheniere Class B Units Holdings, LLC, our wholly owned subsidiary.  As a result of the two transactions, we received net cash of $313.9 million.

Approximately one-half of the receiving capacity at the Sabine Pass LNG terminal is contracted to two multinational energy companies. The other half is held by Sabine Pass Liquefaction for use in connection with the Liquefaction Project. One of our wholly owned subsidiaries, Cheniere Marketing, LLC ("Cheniere Marketing"), markets LNG on its own behalf, and through a series of agreements, has the right to utilize the regasification capacity held by Sabine Pass Liquefaction during the construction phase of the Liquefaction Project. Cheniere Marketing also holds a 104.0 million MMBtu per year LNG sale and purchase agreement ("SPA") with Sabine Pass Liquefaction under which it has the right to purchase LNG from Sabine Pass Liquefaction for a tiered incentive-based fee.

We are also in various stages of developing other projects, including LNG facilities and associated pipelines, each of which, among other things, will require acceptable commercial and financing arrangements before we make a final investment decision.

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

NOTE 2—BASIS OF PRESENTATION

The accompanying unaudited Consolidated Financial Statements of Cheniere Energy, Inc. have been prepared in accordance with generally accepted accounting principles in the United States ("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.

Results of operations for the three and nine months ended September 30, 2013 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2013.

Certain reclassifications have been made to prior period information to conform to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows. 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, 2012, as amended by Amendment No. 1 on Form 10-K/A.

6

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 3—RESTRICTED CASH AND CASH EQUIVALENTS

Restricted cash and cash equivalents consist 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.

Amounts that are designated as restricted cash and cash equivalents are contractually restricted as to usage or withdrawal and will not become available to us as cash and cash equivalents. For these amounts, we have presented increases and decreases as "Investments in (uses of) of restricted cash and cash equivalents" in our Consolidated Statement of Cash Flows. These amounts that represent non-cash transactions within our Consolidated Statement of Cash Flows present the effect of sources and uses of restricted cash and cash equivalents as they relate to the changes to assets and liabilities in our Consolidated Balance Sheets. This presentation does not impact the total amount of operating, investing or financing cash flows related to these items, however , they are presented on a gross basis within each of those categories so as to reconcile the change in non-cash activity that occurs on the balance sheet from period to period.

Restricted cash and cash equivalents include the following:

Sabine Pass LNG Senior Notes Debt Service Reserve

Sabine Pass LNG, L.P. ("Sabine Pass LNG") has consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of Senior Secured Notes due 2016 (the "2016 Notes") and $420.0 million of Senior Secured Notes due 2020 (the "2020 Notes") (See Note 8—"Long-Term Debt"). Collectively, the 2016 Notes and the 2020 Notes are referred to as the "Sabine Pass LNG Senior Notes." Under the indentures governing the Sabine Pass LNG Senior Notes (the "Sabine Pass LNG Indentures"), except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied, including that 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 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 Sabine Pass LNG Indentures.

As of September 30, 2013 and December 31, 2012, we classified $53.0 million and $17.4 million, respectively, as current restricted cash and cash equivalents for the payment of interest due within twelve months. As of both September 30, 2013 and December 31, 2012, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash and cash equivalents. These cash accounts are controlled by a collateral trustee, and, therefore, are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets.

Liquefaction Reserve

In July 2012, Sabine Pass Liquefaction closed on a $3.6 billion senior secured credit facility (the "2012 Liquefaction Credit Facility"). In February and April 2013, Sabine Pass Liquefaction entered into $2.0 billion, before premium, of Senior Secured Notes due in 2021 (the "2021 Sabine Pass Liquefaction Senior Notes") and $1.0 billion of Senior Secured Notes due in 2023 (the "2023 Sabine Pass Liquefaction Senior Notes" and collectively with the 2021 Sabine Pass Liquefaction Senior Notes, the "Sabine Pass Liquefaction Senior Notes"). In May 2013, Sabine Pass Liquefaction closed four credit facilities aggregating $5.9 billion (collectively the "2013 Liquefaction Credit Facilities"), which amended and restated the 2012 Liquefaction Credit Facility. See Note 8—"Long-Term Debt". Under the terms and conditions of the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction is required to deposit all cash received into collateral accounts controlled by a collateral trustee. Therefore, all of Sabine Pass Liquefaction's cash and cash equivalents are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets. As of September 30, 2013 and December 31, 2012, we classified $133.5 million and $75.1 million, respectively, as current restricted cash and cash equivalents held by Sabine Pass Liquefaction for the payment of current liabilities related to the Liquefaction Project, and $665.1 million and $196.3 million, respectively, as non-current restricted cash and cash equivalents held by Sabine Pass Liquefaction for future Liquefaction Project construction costs.

CTPL Reserve

7

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

In May 2013, CTPL entered into a $400.0 million term loan facility (the "CTPL Credit Facility"). As of September 30, 2013, we classified $23.5 million and $87.2 million as current and non-current restricted cash and cash equivalents, respectively, held by CTPL because such funds may only be used for modifications of the Creole Trail Pipeline in order to enable bi-directional natural gas flow and for the payment of interest during construction of such modifications.

Other Restricted Cash and Cash Equivalents

As of September 30, 2013 and December 31, 2012, $339.9 million and $419.3 million, respectively, of cash and cash equivalents were held by Sabine Pass LNG and Cheniere Partners that are considered restricted to Cheniere.  As of September 30, 2013 and December 31, 2012, $28.0 million and $8.5 million, respectively, had been classified as current restricted cash and cash equivalents on our Consolidated Balance Sheets due to various other contractual restrictions. As of both September 30, 2013 and December 31, 2012, $0.5 million had been classified as non-current restricted cash and cash equivalents due to various other contractual restrictions on our Consolidated Balance Sheets.

NOTE 4—PROPERTY, PLANT AND EQUIPMENT

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

	September 30,			December 31,
	2013			2012
LNG terminal costs
LNG terminal	$	2,233,748		$	2,233,595
LNG terminal construction-in-process	3,735,876			1,269,798
LNG site and related costs, net	5,766			5,398
Accumulated depreciation	(278,071		)	(235,275		)
Total LNG terminal costs, net	5,697,319			3,273,516
Fixed assets and other
Computer and office equipment	7,808			7,014
Furniture and fixtures	4,167			4,057
Computer software	13,125			13,012
Leasehold improvements	7,226			6,989
Other	7,552			6,844
Accumulated depreciation	(31,630		)	(29,127		)
Total fixed assets, net	8,248			8,789
Property, plant and equipment, net	$	5,705,567		$	3,282,305

LNG Terminal Costs

Depreciation expense related to the Sabine Pass LNG terminal totaled $14.4 million and $14.5 million for the three months ended September 30, 2013 and 2012, respectively. Depreciation expense related to the Sabine Pass LNG terminal totaled $43.0 million for each of the nine months endedSeptember 30, 2013 and 2012.

In June 2012, we began capitalizing costs associated with Train 1 and Train 2 of the Liquefaction Project, and in May 2013, we began capitalizing costs associated with Train 3 and Train 4 of the Liquefaction Project. For the three months ended September 30, 2013 and 2012, we capitalized $30.2 million and $14.0 million of interest expense related to the construction of the Liquefaction Project, respectively. For the nine months endedSeptember 30, 2013 and 2012, we capitalized $125.0 million and $14.0 million of interest expense related to the construction of the Liquefaction Project, respectively.

8

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

Fixed Assets and Other

Depreciation expense related to our fixed assets and other totaled $0.8 million for each of the three months ended September 30, 2013 and 2012. Depreciation expense related to our fixed assets and other totaled $2.5 million and $3.6 million for the nine months endedSeptember 30, 2013 and 2012, respectively.

NOTE 5—VARIABLE INTEREST ENTITY

Cheniere Energy Partners

Cheniere Partners is a master limited partnership formed by us to own and operate the Sabine Pass LNG terminal and related assets. As of September 30, 2013, we owned 57.9% of Cheniere Partners in the form of 12.0 million common units, 45.3 million Class B units, 135.4 million subordinated units and a 2% general partner interest. Cheniere Energy Partners GP, LLC ("Cheniere Partners GP"), our wholly owned subsidiary, is the general partner of Cheniere Partners. In May 2012, Cheniere Partners, Cheniere and Blackstone entered into the Blackstone Unit Purchase Agreement whereby Cheniere Partners agreed to sell to Blackstone in a private placement 100.0 million Class B units at a price of $15.00 per Class B unit. In August 2012, all conditions to funding were met and Blackstone purchased its initial 33.3 million Class B units, and as of December 31, 2012, Blackstone had purchased the remaining 66.7 million Class B units. At initial funding, the board of directors of Cheniere Partners GP was modified to include three directors appointed by Blackstone, four directors appointed by us and four independent directors mutually agreed by Blackstone and us and appointed by us. In addition, we have provided Blackstone with a right to maintain one board seat on our board of directors. A quorum consists of a majority of all directors, including at least two directors appointed by Blackstone, two directors appointed by us and two independent directors. Blackstone will no longer be entitled to appoint directors in the event that Blackstone's ownership in Cheniere Partners is less than: (i) 20% of outstanding common units, subordinated units and Class B units, and (ii) 50.0 million Class B units.

As a result of contractual changes in the governance of Cheniere Partners GP in connection with the Blackstone Unit Purchase Agreement, we have determined that Cheniere Partners GP is a variable interest entity and that we, as the holder of the equity at risk, do not have a controlling financial interest due to the rights held by Blackstone. However, we continue to consolidate Cheniere Partners as a result of Blackstone's right to maintain one board seat on our board of directors which creates a de facto agency relationship between Blackstone and us. GAAP requires that when a de facto agency relationship exists, one of the members of the de facto agency relationship must consolidate the variable interest entity based on certain criteria. As a result, we consolidate Cheniere Partners in our consolidated financial statements.

NOTE 6—NON-CONTROLLING INTEREST

Cheniere Partners financial statements are consolidated in our consolidated financial statements and we record the partnership's other partners' equity as a non-controlling interest. The following table sets forth the components of our non-controlling interest balance since inception attributable to third-party investors’ interests at September 30, 2013 (in thousands): 

Net proceeds from Cheniere Partners’ issuance of common units (1)	$	719,572
Net proceeds from CLNGH’s sale of Cheniere Partners common units (2)	203,946
Distributions to Cheniere Partners’ non-controlling interest	(207,396		)
Net proceeds from Cheniere Partners' issuance of Class B units (3)	1,387,339
Non-controlling interest share of loss of Cheniere Partners	(76,325		)
Non-controlling interest at September 30, 2013	$	2,027,136

(1) In March and April 2007, we and Cheniere Partners completed a public offering of 15.5 million Cheniere Partners common units (the "Cheniere Partners IPO"). Cheniere Partners received $98.4 million in net proceeds from the issuance of its common units to the public.

In January 2011, Cheniere Partners initiated an at-the-market program to sell up to 1.0 million common units, the proceeds from which would be used primarily to fund development costs associated with the Liquefaction Project. As of December 31, 2011, Cheniere Partners had sold 0.5 million common units with net proceeds of $9.0 million. During the year endedDecember 31, 2012, Cheniere Partners sold 0.5 million common units with net proceeds of $11.1 million.

9

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

In September 2011, Cheniere Partners sold 3.0 million common units in an underwritten public offering and 1.1 million common units to Cheniere Common Units Holding, LLC, a wholly owned subsidiary of Cheniere, at a price of $15.25 per common unit. Cheniere Partners received net proceeds of $43.3 million and $16.4 million from the public offering and Cheniere Common Units Holding, LLC sale, respectively.

In September 2012, Cheniere Partners sold 8.0 million common units in an underwritten public offering at a price of $25.07 per common unit for net cash proceeds of $194.0 million.

In March 2013, Cheniere Partners sold 17.6 million common units in a registered direct offering to institutional investors at a price of $20.75 per common unit for net proceeds of $364.8 million.

(2) In conjunction with the Cheniere Partners IPO, Cheniere LNG Holdings, LLC ("CLNGH") sold a portion of the Cheniere Partners common units held by it to the public, realizing net proceeds of $203.9 million, which included $39.4 million of net proceeds realized once the underwriters exercised their option to purchase an additional 2.0 million common units from Holdings.

(3) In May 2012, Cheniere Partners, Cheniere and Blackstone CQP Holdco LP ("Blackstone") entered into a unit purchase agreement (the "Blackstone Unit Purchase Agreement") whereby Cheniere Partners agreed to sell to Blackstone in a private placement 100.0 million Class B units of Cheniere Partners ("Class B units") at a price of $15.00 per Class B unit. Cheniere Partners had issued and sold all 100.0 million Class B units to Blackstone as of December 31, 2012. See Note 5—"Variable Interest Entity".

NOTE 7—ACCRUED LIABILITIES

As of September 30, 2013 and December 31, 2012, accrued liabilities consisted of the following (in thousands): 

	September 30,		December 31,
	2013		2012
Accrued interest expense and related fees	$	97,758	$	16,327
Payroll	25,693		6,369
LNG liquefaction costs	33,956		27,919
LNG terminal costs	1,650		977
Other accrued liabilities	12,958		7,145
Accrued liabilities	$	172,015	$	58,737

NOTE 8—LONG-TERM DEBT

As of September 30, 2013 and December 31, 2012, our long-term debt consisted of the following (in thousands): 

	September 30,			December 31,
	2013			2012
Long-term debt
2016 Notes	$	1,665,500		$	1,665,500
2020 Notes	420,000			420,000
2021 Sabine Pass Liquefaction Senior Notes	2,000,000			—
2023 Sabine Pass Liquefaction Senior Notes	1,000,000			—
2012 Liquefaction Credit Facility	—			100,000
2013 Liquefaction Credit Facilities	100,000			—
CTPL Credit Facility	400,000			—
Total long-term debt	5,585,500			2,185,500
Long-term debt premium (discount)
2016 Notes	(14,866		)	(18,387		)
2021 Sabine Pass Liquefaction Senior Notes	11,897			—
CTPL Credit Facility	(8,336		)	—
Total long-term debt, net	$	5,574,195		$	2,167,113

10

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

Sabine Pass LNG Senior Notes

As of September 30, 2013 and December 31, 2012, Sabine Pass LNG had an aggregate principal amount of $1,665.5 million, before discount, of the 2016 Notes and $420.0 million of the 2020 Notes outstanding. Borrowings under the 2016 Notes and 2020 Notes bear interest at a fixed rate of 7.50% and 6.50%, respectively. The terms of the 2016 Notes and the 2020 Notes are substantially similar. Interest on the 2016 Notes is payable semi-annually in arrears on May 30 and November 30 of each year. Interest on the 2020 Notes is payable semi-annually in arrears on May 1 and November 1 of each year. Subject to permitted liens, the Sabine Pass LNG Senior Notes are secured on a first-priority basis by a security interest in all of Sabine Pass LNG's equity interests and substantially all of its operating assets.

Sabine Pass LNG may redeem some or all of its 2016 Notes at any time, and from time to time, at the redemption prices specified in the indenture governing the 2016 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may redeem all or part of its 2020 Notes at any time on or after November 1, 2016, at fixed redemption prices specified in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may also, at its option, redeem all or part of the 2020 Notes at any time prior to November 1, 2016, at a "make-whole" price set forth in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, Sabine Pass LNG may redeem up to 35% of the aggregate principal amount of the 2020 Notes at a redemption price of 106.5% of the principal amount of the 2020 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 Sabine Pass LNG redeems the 2020 Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Notes originally issued remains outstanding after the redemption.

Under the Sabine Pass LNG Indentures, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied: 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 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 Sabine Pass LNG Indentures. During the three months ended September 30, 2013 and 2012, Sabine Pass LNG made distributions of $93.0 million and $36.2 million, respectively, after satisfying all the applicable conditions in the Sabine Pass LNG Indentures. During the nine months ended September 30, 2013 and 2012, Sabine Pass LNG made distributions of $242.1 million and $182.9 million, respectively, after satisfying all the applicable conditions in the Sabine Pass LNG Indentures.

Sabine Pass Liquefaction Senior Notes

In February 2013 and April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $2.0 billion, before premium, of the 2021 Sabine Pass Liquefaction Senior Notes. In April 2013, Sabine Pass Liquefaction also issued $1.0 billion of the 2023 Sabine Pass Liquefaction Senior Notes. Borrowings under the Sabine Pass Liquefaction Senior Notes bear interest at a fixed rate of 5.625%. Interest on the 2021 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on February 1 and August 1 of each year. Interest on the 2023 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on April 15 and October 15 of each year.

The terms of the 2021 Sabine Pass Liquefaction Senior Notes and the 2023 Sabine Pass Liquefaction Senior Notes are governed by a common indenture (the "Indenture"). The Indenture contains customary terms and events of default and certain covenants that, among other things, limit Sabine Pass Liquefaction's ability and the ability of Sabine Pass Liquefaction's restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of Sabine Pass Liquefaction's restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, consolidate, merge, sell or lease all or substantially all of Sabine Pass Liquefaction's assets and enter into certain LNG sales contracts. Subject to permitted liens, the Sabine Pass Liquefaction Senior Notes are secured on a pari passu first-priority basis by a security interest in all of the membership interests in Sabine Pass Liquefaction and substantially all of Sabine Pass Liquefaction's assets. Sabine Pass Liquefaction may not make any distributions until, among other requirements, substantial completion of Train 1 and Train 2 has occurred, deposits are made into debt service reserve accounts

11

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

and a debt service coverage ratio for the prior 12-month period and a projected debt service coverage ratio for the upcoming 12-month period of 1.25:1.00 are satisfied.

At any time prior to November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction may redeem all or a part of the Sabine Pass Liquefaction Senior Notes, at a redemption price equal to the "make-whole" price set forth in the Indenture, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass Liquefaction also may at any time on or after November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, redeem the Sabine Pass Liquefaction Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the Sabine Pass Liquefaction Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

In connection with the issuances of the Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction also entered into registration rights agreements (the "Liquefaction Registration Rights Agreements"). Under the Liquefaction Registration Rights Agreements, Sabine Pass Liquefaction has agreed to use commercially reasonable efforts to file with the SEC and cause to become effective registration statements relating to an offer to exchange the Sabine Pass Liquefaction Senior Notes for a like aggregate principal amount of SEC-registered notes with terms identical in all material respects to the 2021 Sabine Pass Liquefaction Senior Notes and 2023 Sabine Pass Liquefaction Senior Notes (other than with respect to restrictions on transfer or to any increase in annual interest rate) within 360 days after February 1, 2013 for $1.5 billion of the 2021 Sabine Pass Liquefaction Senior Notes and within 295 days after April 16, 2013 for $500.0 million of the 2021 Sabine Pass Liquefaction Senior Notes and all of the 2023 Sabine Pass Liquefaction Senior Notes. Under specified circumstances, Sabine Pass Liquefaction may be required to file a shelf registration statement to cover resales of the Sabine Pass Liquefaction Senior Notes. If Sabine Pass Liquefaction fails to satisfy these obligations, Sabine Pass Liquefaction may be required to pay additional interest to holders of the Sabine Pass Liquefaction Senior Notes under certain circumstances.

2013 Liquefaction Credit Facilities

In May 2013, Sabine Pass Liquefaction closed the 2013 Liquefaction Credit Facilities aggregating $5.9 billion. The 2013 Liquefaction Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation the first four LNG Trains of the Liquefaction Project. The 2013 Liquefaction Credit Facilities will mature on the earlier of May 28, 2020 or the second anniversary of the completion date of the first four LNG Trains of the Liquefaction Project, as defined in the 2013 Liquefaction Credit Facilities. Borrowings under the 2013 Liquefaction Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent.

Borrowings under the 2013 Liquefaction Credit Facilities bear interest at a variable rate per annum equal to, at Sabine Pass Liquefaction's election, the London Interbank Offered Rate ("LIBOR") or the base rate, plus the applicable margin. The applicable margins for LIBOR loans prior to, and after, the completion of Train 4 range from 2.3% to 3.0% and 2.3% to 3.25%, respectively, depending on the applicable 2013 Liquefaction Credit Facility. Interest on LIBOR loans is due and payable at the end of each LIBOR period. The 2013 Liquefaction Credit Facilities required Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $144.0 million and provide for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment. Annual administrative fees must also be paid to the agent and the trustee. The principal of loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing upon the earlier of the last day of the first calendar quarter ending at least three months following the completion of Train 4 of the Liquefaction Project and September 30, 2018. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2013 Liquefaction Credit Facilities.

Under the terms and conditions of the 2013 Liquefaction Credit Facilities, all cash held by Sabine Pass Liquefaction is controlled by a collateral agent. These funds can only be released by the collateral agent upon satisfaction of certain terms and conditions related to the use of proceeds, and are classified as restricted on our Consolidated Balance Sheets.

12

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

The 2013 Liquefaction Credit Facilities contain conditions precedent for the second borrowing and any subsequent borrowings, as well as customary affirmative and negative covenants. The obligations of Sabine Pass Liquefaction under the 2013 Liquefaction Credit Facilities are secured by substantially all of the assets of Sabine Pass Liquefaction as well as all of the membership interests in Sabine Pass Liquefaction on a pari passu basis with the Sabine Pass Liquefaction Senior Notes.

Under the terms of the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction is required to hedge not less than 75% 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. See Note 9— "Financial Instruments".

2012 Liquefaction Credit Facility

In July 2012, Sabine Pass Liquefaction entered into the $3.6 billion 2012 Liquefaction Credit Facility with a syndicate of lenders. The 2012 Liquefaction Credit Facility was intended to be used to fund a portion of the costs of developing, constructing and placing into operation Train 1 and Train 2 of the Liquefaction Project. In May 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities and $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full.

The 2012 Liquefaction Credit Facility had a maturity date of the earlier of July 31, 2019 or the second anniversary of the completion date of Train 1 and Train 2 of the Liquefaction Project, as defined in the 2012 Liquefaction Credit Facility. Borrowings under the 2012 Liquefaction Credit Facility could have been refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2012 Liquefaction Credit Facility in August 2012 after meeting the required conditions precedent.

Borrowings under the 2012 Liquefaction Credit Facility bore interest at a variable rate equal to, at Sabine Pass Liquefaction's election, LIBOR or the base rate, plus the applicable margin. The applicable margin for LIBOR loans was 3.50% during construction and 3.75% during operations. Interest on LIBOR loans was due and payable at the end of each LIBOR period. The 2012 Liquefaction Credit Facility required Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $178 million and provided for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment. Annual administrative fees were also required to be paid to the agent and the trustee. The principal of loans made under the 2012 Liquefaction Credit Facility had to be repaid in quarterly installments, commencing with the last day of the first calendar quarter ending at least three months following the completion of Train 1 and Train 2 of the Liquefaction Project. Scheduled repayments were based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2012 Liquefaction Credit Facility.

Under the terms and conditions of the 2012 Liquefaction Credit Facility, all cash held by Sabine Pass Liquefaction was controlled by the collateral agent. These funds could only be released by the collateral agent upon satisfaction of certain terms and conditions related to the use of proceeds, and the cash balance of $100.0 million held in these accounts as of December 31, 2012 was classified as restricted on our Consolidated Balance Sheets.

The 2012 Liquefaction Credit Facility contained conditions precedent for the second borrowing and any subsequent borrowings, as well as customary affirmative and negative covenants. The obligations of Sabine Pass Liquefaction under the 2012 Liquefaction Credit Facility were secured by substantially all of the assets of Sabine Pass Liquefaction as well as all of the membership interests in Sabine Pass Liquefaction, and a security interest in Cheniere Partners' rights under its Unit Purchase Agreement with Blackstone CQP Holdco LP dated May 14, 2012 on a pari passu basis with the Sabine Pass Liquefaction Senior Notes.

Under the terms of the 2012 Liquefaction Credit Facility, Sabine Pass Liquefaction was required to hedge not less than 75% 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. See Note 9—"Financial Instruments".

13

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

In February 2013, Sabine Pass Liquefaction issued the 2021 Sabine Pass Liquefaction Senior Notes to refinance a portion of the 2012 Liquefaction Credit Facility, and a portion of available commitments pursuant to the 2012 Liquefaction Credit Facility was suspended. In April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $500.0 million of additional 2021 Sabine Pass Liquefaction Senior Notes and $1.0 billion of 2023 Sabine Pass Liquefaction Senior Notes, and as a result, approximately $1.4 billion of commitments under the 2012 Liquefaction Credit Facility were terminated. The termination of these commitments in April 2013 and the amendment and restatement of the 2012 Liquefaction Credit Facility with the 2013 Liquefaction Credit Facilities in May 2013 resulted in a write-off of debt issuance costs associated with the 2012 Liquefaction Credit Facility of zero and $80.5 million in the three and nine months ended September 30, 2013, respectively.

CTPL Credit Facility

In May 2013, CTPL entered into the CTPL Credit Facility, which will be used to fund modifications to the Creole Trail Pipeline and for general business purposes. CTPL incurred $10.0 million of direct lender fees that were recorded as a debt discount. The CTPL Credit Facility matures in 2017 when the full amount of the outstanding principal obligations must be repaid. CTPL's loans may be repaid, in whole or in part, at any time without premium or penalty. As of September 30, 2013, CTPL had borrowed the full amount of $400.0 million available under the CTPL Credit Facility.

Borrowings under the CTPL Credit Facility bear 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.

Under the terms and conditions of the CTPL 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. CTPL is also required to pay annual fees to the administrative and collateral agents.

The CTPL Credit Facility contains customary affirmative and negative covenants. The obligations of CTPL under the CTPL Credit Facility are secured by a first priority lien on substantially all of the personal property of CTPL and all of the general partner and limited partner interests in CTPL.

Cheniere Partners has guaranteed (i) the obligations of CTPL under the CTPL Credit Facility if the maturity of the CTPL loans is accelerated following the termination by Sabine Pass Liquefaction of a transportation precedent agreement in limited circumstances and (ii) the obligations of Cheniere Energy Investments, LLC ("Cheniere Investments"), Cheniere Partners' wholly owned subsidiary, in connection with its obligations under an equity contribution agreement (a) to pay operating expenses of CTPL until CTPL receives revenues under a service agreement with Sabine Pass Liquefaction and (b) to fund interest payments on the CTPL loans after the funds in an interest reserve account have been exhausted.

NOTE 9—FINANCIAL INSTRUMENTS

Derivative Instruments

We have entered into certain instruments to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory ("LNG Inventory Derivatives") and to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate the Sabine Pass LNG terminal ("Fuel Derivatives"), and interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities ("Interest Rate Derivatives").

14

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of September 30, 2013 and December 31, 2012, which are classified as other current assets, other current liabilities and other non-current liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	September 30, 2013										December 31, 2012
	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
LNG Inventory Derivatives asset	$	—	$	186		$	—	$	186		$	—	$	237		$	—	$	237
Fuel Derivatives (liability)	—		(283		)	—		(283		)	—		(98		)	—		(98		)
Interest Rate Derivatives asset (liability)	—		56,039			—		56,039			—		(26,424		)	—		(26,424		)

The estimated fair values of our LNG Inventory Derivatives and Fuel Derivatives are the amount 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. 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 derivative instruments that qualify for derivative accounting treatment as either assets or liabilities and measure those instruments at fair value.  For those instruments accounted for as derivatives, including our LNG Inventory Derivatives and certain of our Fuel Derivatives, changes in fair value are reported in earnings.

The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances where our Fuel Derivatives or our LNG Inventory Derivatives are in an asset position. Our commodity derivative transactions 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 commodity derivative activities.  Collateral of $6.1 million and $5.9 million deposited for such contracts, which has not been reflected in the derivative fair value tables, is included in the other current assets balance as of September 30, 2013, and December 31, 2012, respectively.

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

		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2013			December 31, 2012
LNG Inventory Derivatives asset	Prepaid expenses and other	$	186		$	237
Fuel Derivatives (liability)	Prepaid expenses and other	(283		)	(98		)

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in marketing and trading revenues (losses) on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
LNG Inventory Derivatives gain (loss)	$	14		$	(265	)	$	(394	)	$	599
Fuel Derivatives loss	(57		)	—			(57		)	—

15

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013			2012		2013			2012
LNG Inventory Derivatives gain	$	201		$	—	$	976		$	—
Fuel Derivatives gain (loss)	(55		)	287		(3		)	(288		)

Interest Rate Derivatives

In August 2012 and June 2013, Sabine Pass Liquefaction entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, respectively. The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2013 Liquefaction Credit Facilities.

Sabine Pass Liquefaction designated the Interest Rate Derivatives entered into in August 2012 as hedging instruments which was required in order to qualify for cash flow hedge accounting. As a result of this cash flow hedge designation, we recognized the Interest Rate Derivatives entered into in August 2012 as an asset or liability at fair value, and reflected changes in fair value through other comprehensive income in our Consolidated Statements of Comprehensive Loss. Any hedge ineffectiveness associated with the Interest Rate Derivatives entered into in August 2012 was recorded immediately as derivative gain (loss) in our Consolidated Statements of Operations. The realized gain (loss) on the Interest Rate Derivatives entered into in August 2012 was recorded as an (increase) decrease in interest expense on our Consolidated Statements of Operations to the extent not capitalized as part of the Liquefaction Project. The effective portion of the gains or losses on our Interest Rate Derivatives entered into in August 2012 recorded in other comprehensive income would have been reclassified to earnings as interest payments on the 2012 Liquefaction Credit Facility impact earnings. In addition, amounts recorded in other comprehensive income are also reclassified into earnings if it becomes probable that the hedged forecasted transaction will not occur.

Sabine Pass Liquefaction did not elect to designate the Interest Rate Derivatives entered into in June 2013 as cash flow hedging instruments, and changes in fair value are recorded as derivative gain (loss), net within the Consolidated Statements of Operations.

During the first quarter of 2013, we determined that it was no longer probable that the forecasted variable interest payments on the 2012 Liquefaction Credit Facility would occur in the time period originally specified based on the continued development of our financing strategy for the Liquefaction Project, and, in particular, the Sabine Pass Liquefaction Senior Notes described in Note 8—"Long-Term Debt". As a result, all of the Interest Rate Derivatives entered into in August 2012 were no longer effective hedges, and the remaining portion of hedge relationships that were designated cash flow hedges as of December 31, 2012, were de-designated as of February 1, 2013. For de-designated cash flow hedges, changes in fair value prior to their de-designation date were recorded as other comprehensive income (loss) within the Consolidated Balance Sheets, and changes in fair value subsequent to their de-designation date were recorded as derivative gain (loss) within the Consolidated Statements of Operations.

In June 2013, we concluded that the hedged forecasted transactions associated with the Interest Rate Derivatives entered into in connection with the 2012 Liquefaction Credit Facility had become probable of not occurring based on the issuances of the Sabine Pass Liquefaction Senior Notes, the closing of the 2013 Liquefaction Credit Facilities, the additional Interest Rate Derivatives executed in June 2013, and our intention to continue to issue fixed rate debt to refinance drawn portions of the 2013 Liquefaction Credit Facilities. As a result, the amount remaining in accumulated other comprehensive income ("AOCI") pertaining to the previously designated Interest Rate Derivatives was reclassified out of AOCI and into income. We have presented the reclassification of unrealized losses from AOCI into income and the changes in fair value and settlements subsequent to the reclassification date separate from interest expense as derivative gain (loss), net in our Consolidated Statements of Operations.

16

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

At September 30, 2013, Sabine Pass Liquefaction 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
Interest Rate Derivatives - Not Designated	$20.0 million	$2.9 billion	August 14, 2012	July 31, 2019	1.98%	One-month LIBOR
Interest Rate Derivatives - Not Designated	—	$671.0 million	June 5, 2013	May 28, 2020	2.05%	One-month LIBOR

The following table (in thousands) shows the fair value of our Interest Rate Derivatives:

		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2013		December 31, 2012
Interest Rate Derivatives - Not Designated	Non-current derivative assets	$	64,309	$	—
Interest Rate Derivatives - Designated	Non-current derivative liabilities	—		21,290
Interest Rate Derivatives - Not Designated	Other current liabilities	8,270		—
Interest Rate Derivatives - Not Designated	Non-current derivative liabilities	—		5,134

The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the three months ended September 30, 2013 and 2012:

	Gain (Loss) in Other Comprehensive Income					Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	2013		2012			2013		2012		2013		2012
Interest Rate Derivatives - Designated	$	—	$	(29,676	)	$	—	$	—	$	—	$	—

The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the nine months endedSeptember 30, 2013 and 2012:

	Gain (Loss) in Other Comprehensive Income						Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	2013			2012			2013		2012		2013			2012
Interest Rate Derivatives - Designated	$	21,297		$	(29,676	)	$	—	$	—	$	(5,806	)	$	—
Interest Rate Derivatives - Settlements	(30		)	—			—		—		(167		)	—

The following table (in thousands) shows the changes in the fair value of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013			2012		2013		2012
Interest Rate Derivatives - Not Designated gain (loss)	$	(22,481	)	$	—	$	60,707	$	—

17

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

Balance Sheet Presentation

Our commodity 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 Sheet			Net Amounts Presented in the Consolidated Balance Sheet			Gross Amounts Not Offset in the Consolidated Balance Sheet
Offsetting Derivative Assets (Liabilities)										Derivative Instrument		Cash Collateral Received (Paid)		Net Amount
As of September 30, 2013:
Fuel Derivatives	$	(283	)	$	(283	)	$	—		$	—	$	—	$	—
LNG Inventory Derivatives	186						186			—		—		186
Interest Rate Derivatives - Not Designated	64,309			—			64,309			—		—		64,309
Interest Rate Derivatives - Not Designated	(8,270		)	—			(8,270		)	—		—		(8,270		)
As of December 31, 2012:
Fuel Derivatives	(98		)	(98		)	—			—		—		—
LNG Inventory Derivatives	237			—			237			—		—		237
Interest Rate Derivatives - Designated	(21,290		)	—			(21,290		)	—		—		(21,290		)
Interest Rate Derivatives - Not Designated	(5,134		)	—			(5,134		)	—		—		(5,134		)

Other Financial Instruments

The estimated fair value of our other financial instruments, including those financial instruments for which the fair value option was not elected, are set forth in the table below.  The carrying amounts reported on our Consolidated Balance Sheets for cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, interest receivable and accounts payable approximate fair value due to their short-term nature.

Other Financial Instruments (in thousands):

	September 30, 2013				December 31, 2012
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 Notes, net of discount (1)	$	1,650,634	$	1,811,570	$	1,647,113	$	1,824,177
2020 Notes (1)	420,000		425,250		420,000		437,850
2021 Sabine Pass Liquefaction Senior Notes (1)	2,011,897		1,951,540		—		—
2023 Sabine Pass Liquefaction Senior Notes (1)	1,000,000		952,500		—		—
2012 Liquefaction Credit Facility (2)	—		—		100,000		100,000
2013 Liquefaction Credit Facilities (2)	100,000		100,000		—		—
CTPL Credit Facility (3)	391,665		400,000		—		—

(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 September 30, 2013 and December 31, 2012, as applicable.

(2) The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and Sabine Pass Liquefaction has the ability to call this debt at anytime without penalty.

(3) The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and CTPL has the ability to call this debt at anytime without penalty. 

18

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 10—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 financial statements. However, we are presently an international taxpayer and have recorded a net expense of $1.8 million and $0.1 million for international income taxes for the three months ended September 30, 2013 and 2012, respectively. We recorded a net expense of $2.8 million and $0.2 million for international income taxes for the nine months ended September 30, 2013 and 2012, respectively.

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 11—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 nine months ended September 30, 2013 and 2012 (in thousands except for loss per share):

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Weighted average common shares outstanding:
Basic	220,734			208,712			217,940			170,414
Dilutive common stock options (1)	—			—			—			—
Diluted	220,734			208,712			217,940			170,414
Basic and diluted net loss per share attributable to common stockholders	$	(0.46	)	$	(0.52	)	$	(1.71	)	$	(1.40	)

(1) Stock options and unvested stock of 18.3 million shares and 16.5 million shares representing securities that could potentially dilute basic EPS in the future were not included in the diluted net loss per share computations for the three and nine months ended September 30, 2013, respectively, because they would have been anti-dilutive. Stock options and unvested stock of 5.6 million shares and 3.1 million shares representing securities that could potentially dilute basic EPS in the future were not included in the diluted net loss per share computations for the three and nine months ended September 30, 2012, respectively, because they would have been anti-dilutive.

19

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 12—SHARE-BASED COMPENSATION

We have granted options to purchase common stock to employees, consultants and outside directors 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"), and 2011 Incentive Plan, as amended (the "2011 Plan"). We recognize our share-based payments to employees in the consolidated financial statements based on their fair values at the date of grant. The calculated fair value is recognized as expense (net of any capitalization) over the requisite service period, net of estimated forfeitures, using the straight-line or accelerated recognition methods.

For the three months ended September 30, 2013 and 2012, the total share-based compensation expense recognized in our net loss (net of capitalization) was $26.7 million and $49.8 million, respectively. For the nine months endedSeptember 30, 2013 and 2012, the total share-based compensation expense recognized in our net loss (net of capitalization) was $202.8 million and $54.0 million, respectively.  For the three months ended September 30, 2013 and 2012, the total share-based compensation cost capitalized as part of the cost of capital assets was $1.3 million and $2.2 million, respectively. For the nine months endedSeptember 30, 2013 and 2012, the total share-based compensation cost capitalized as part of the cost of capital assets was $8.6 million and $2.2 million, respectively.

The total unrecognized compensation cost at September 30, 2013 relating to non-vested share-based compensation arrangements granted under the 1997 Plan, 2003 Plan and 2011 Plan was $283.7 million. That cost is expected to be recognized over 5.5 years, with a weighted average period of 3.4 years.

We received $0.3 million of proceeds from the exercise of stock options in the three and nine months ended September 30, 2013 and $0.8 million of proceeds from the exercise of stock options in the three and nine months ended September 30, 2012.

Long-Term Commercial Bonus Awards for Train 3 and Train 4 under the 2011-2013 Bonus Plan

On December 12, 2012, pursuant to the 2011-2013 Bonus Plan, the Compensation Committee approved a Long-Term Bonus Pool for 2012 for all employees of the Company consisting of a total of 18 million shares of restricted stock. The Long-Term Commercial Bonus Awards for Train 3 and Train 4 of the Liquefaction Project were granted to employees in February 2013 under the 2003 Plan and 2011 Plan. A portion of each employee's Long-Term Commercial Bonus Award for Train 3 and Train 4 of the Liquefaction Project was granted as a milestone award ("Milestone Award"), with vesting of the Milestone Award conditional on certain performance milestones relating to financing and constructing Train 3 and Train 4 of the Liquefaction Project, and a portion was granted as a stock price award ("Stock Price Award"), with vesting of the Stock Price Award conditional on the achievement of minimum average Company stock price hurdles.

On May 22, 2013, the $25 stock price hurdle was achieved. Following certification by a subcommittee of the compensation committee, fifty percent (50%) of the Stock Price Awards vested. The remaining Stock Price Awards will vest if the average 120-day closing stock price of the Company is $35.

On May 28, 2013, the first performance milestone was achieved when Sabine Pass Liquefaction closed the financing, and issued notice to proceed with construction under the engineering, procurement and construction contract for the construction of Train 3 and Train 4 of the Liquefaction Project (the "EPC Contract (Train 3 and Train 4)"). Following certification of the achievement of the performance milestone by a subcommittee of the compensation committee, thirty percent (30%) of the Milestone Awards vested. The remaining Milestone Awards will vest based on the achievement of the following performance milestones:

• 20% upon payment of 60% of the original contract price of the EPC Contract (Train 3 and Train 4);

• 20% upon substantial completion, as defined in the EPC Contract (Train 3 and Train 4), of Train 4 of the Liquefaction Project; and

• 30% on the first anniversary of substantial completion of Train 4 of the Liquefaction Project.

20

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 13—BUSINESS SEGMENT INFORMATION

We have two operating business segments: LNG terminal business and LNG and natural gas marketing business. We determine our reporting units by identifying each unit 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 makers for purposes of resource allocation and performance assessment, and had discrete financial information.

Our LNG terminal business segment consists of the operational Sabine Pass LNG terminal, approximately 57.9% owned (at September 30, 2013), located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast, and two other LNG terminals that are in various stages of development at the following locations: Corpus Christi LNG, 100% owned, near Corpus Christi, Texas; and Creole Trail LNG, 100% owned, at the mouth of the Calcasieu Channel in central Cameron Parish, Louisiana. The Sabine Pass LNG terminal includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with capacity of up to 265,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d, and pipeline facilities interconnecting the Sabine Pass LNG terminal with a number of large interstate pipelines. Cheniere Partners is currently developing the Liquefaction Project at the Sabine Pass LNG terminal adjacent to the existing regasification facilities. During the fourth quarter of 2012, we merged our natural gas pipeline business segment into our LNG terminal business segment because we were no longer developing or making resource allocation decisions on other pipeline projects not primarily related to our LNG terminals. We have adjusted the corresponding items of segment information for 2012 to reflect this change.

Our LNG and natural gas marketing business segment consists of Cheniere Marketing marketing LNG and natural gas on its own behalf and on behalf of Cheniere Partners in an effort to utilize the receiving capacity held at the Sabine Pass LNG terminal during construction of the Liquefaction Project.

21

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

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

	Segments
	LNG Terminal			LNG & Natural Gas Marketing				Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended September 30, 2013
Revenues (2)	$	67,558		$	16,470			$	(16,318	)	$	67,710
Intersegment revenues (losses) (3) (4)	820			15,880				(16,700		)	—
Depreciation, depletion and amortization	14,581			251				414			15,246
Non-cash compensation	3,148			4,594				20,197			27,939
Income (loss) from operations	(49,600		)	2,919				805			(45,876		)
Interest expense, net	(55,378		)	—				2,850			(52,528		)
Income (loss) before income taxes and non-controlling interest	(127,202		)	2,515				4,013			(120,674		)
Goodwill	76,819			—				—			76,819
Total assets	7,719,551			63,756				342,546			8,125,853
Expenditures for additions to long-lived assets	852,847			61				389			853,297
As of or for the Three Months Ended September 30, 2012
Revenues (2)	$	69,868		$	2,661		—	$	(6,531	)	$	65,998
Intersegment revenues (losses) (3) (4)	3,929			2,953				(6,882		)	—
Depreciation, depletion and amortization	14,566			256				411			15,233
Non-cash compensation	6,505			9,256				36,104			51,865
Loss from operations	(16,446		)	(16,462		)		(21,609		)	(54,517		)
Interest expense, net	(55,333		)	12				9,817			(45,504		)
Income (loss) before income taxes and non-controlling interest	(71,335		)	418,655				(459,135		)	(111,815		)
Goodwill	76,819			—				—			76,819
Total assets	4,136,574			42,308				204,843			4,383,725
Expenditures for additions to long-lived assets	883,798			(6		)		696			884,488
For the Nine Months Ended September 30, 2013
Revenues (2)	$	201,408		$	27,627			$	(28,242	)	$	200,793
Intersegment revenues (losses) (3) (4)	2,184			27,186				(29,370		)	—
Depreciation, depletion and amortization	43,405			751				1,377			45,533
Non-cash compensation	22,477			36,234				152,635			211,346
Loss from operations	(103,655		)	(39,543		)		(106,410		)	(249,608		)
Interest expense, net	(156,644		)	—				21,838			(134,806		)
Income (loss) before income taxes and non-controlling interest	128,441			(40,092		)		(496,613		)	(408,264		)
Expenditures for additions to long-lived assets	2,467,210			57				1,293			2,468,560
For the Nine Months Ended September 30, 2012
Revenues (2)	$	206,249		$	977			$	(8,427	)	$	198,799
Intersegment revenues (losses) (3) (4)	6,973			2,618				(9,591		)	—
Depreciation, depletion and amortization	43,810			1,815				1,376			47,001
Non-cash compensation	6,964			10,657				38,492			56,113
Income (loss) from operations	7,237			(31,788		)		(35,366		)	(59,917		)
Interest expense, net	(165,251		)	12				5,520			(159,719		)
Loss before income taxes and non-controlling interest	(158,016		)	403,369				(491,875		)	(246,522		)
Expenditures for additions to long-lived assets	931,542			1,659				1,192			934,393

(1) Includes corporate activities, oil and gas exploration, development and exploitation activities and certain intercompany eliminations. Our oil and gas exploration, development and exploitation operating activities have been included in the

22

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

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 and international revenue allocations using a cost plus transfer pricing methodology.

(3) Intersegment revenues related to our LNG terminal business segment are primarily from tug revenues from Cheniere Marketing and the receipt of 80% of gross margins earned by Cheniere Marketing in an effort to utilize the reserved capacity at the Sabine Pass LNG terminal of Cheniere Investments under its terminal use rights assignment and agreement ("TURA") pursuant to which Cheniere Investments has the right to use Sabine Pass Liquefaction's reserved capacity at the Sabine Pass LNG terminal under Sabine Pass Liquefaction's TUA in the three and nine months ended September 30, 2013 and 2012. These LNG terminal business segment intersegment revenues are eliminated with intersegment expenses in our Consolidated Statements of Operations.

(4) Intersegment revenues (losses) related to our LNG and natural gas marketing business segment are primarily from Cheniere Marketing's tug costs and the payment of 80% of gross margins earned by Cheniere Marketing in an effort to utilize the reserved capacity at the Sabine Pass LNG terminal of Cheniere Investments under its TURA in the three and nine months ended September 30, 2013 and 2012. These LNG and natural gas marketing business segment intersegment costs are eliminated with intersegment revenues in our Consolidated Statements of Operations.

NOTE 14—SUPPLEMENTAL CASH FLOW INFORMATION AND DISCLOSURES OF NON-CASH TRANSACTIONS

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

	Nine Months Ended September 30,
	2013		2012
Cash paid during the year for interest, net of amounts capitalized and deferred	$	56,428	$	117,190
LNG terminal costs funded with accounts payable and accrued liabilities	80,557		52,830

23

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

    OPERATION

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 fact, 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 liquefied natural gas ("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, regardless of the source of such information, or the transportation 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 natural gas liquefaction trains ("Trains"), including statements concerning the engagement of any engineering, procurement and construction ("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 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 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.

These forward-looking statements are often identified by the use of terms and phrases such as "achieve," "anticipate," "believe,""contemplate," "develop," "estimate," "expect," "forecast," "plan," "potential," "project," "propose," "strategy" and similar terms and phrases, or by the use of future tense. Although we believe that the expectations reflected in these forward-looking statements are reasonable, they do involve assumptions, risks and uncertainties, and these expectations may prove to be incorrect. You should not place undue reliance on these forward-looking statements, which are made as of the date of this quarterly report and speak only as of the date of this quarterly report.

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, 2012, as amended by Amendment No. 1 on Form 10-K/A. 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.

As used herein, the terms "Cheniere," "the Company," "we," "our" and "us" refer to Cheniere Energy, Inc. and its wholly owned or controlled subsidiaries.

24

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 in "Consolidated Financial Statements." 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 Policies and Estimates 

• Recent Accounting Standards

Overview of Business

We own and operate the Sabine Pass LNG terminal in Louisiana through our 57.9% ownership interest in and management agreements with Cheniere Energy Partners, L.P. ("Cheniere Partners") (NYSE MKT: CQP), which is a publicly traded partnership that we created in 2007.  The Sabine Pass LNG terminal is located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast. The Sabine Pass LNG terminal has regasification facilities owned by Cheniere Partners' wholly owned subsidiary, Sabine Pass LNG, L.P. ("Sabine Pass LNG"), that includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with capacity of up to 265,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d. Cheniere Partners is developing natural gas liquefaction facilities (the "Liquefaction Project") at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, Sabine Pass Liquefaction, LLC ("Sabine Pass Liquefaction"). We plan to construct up to six Trains, which are in various stages of development. Each Train is expected to have nominal production capacity of approximately 4.5 million tonnes per annum ("mtpa"). In May 2013, we sold to Cheniere Partners our ownership interests in Cheniere Creole Trail Pipeline, L.P. ("CTPL") and Cheniere Pipeline GP Interests, LLC (collectively, the "Creole Trail Pipeline Business"), thereby providing Cheniere Partners with ownership of a 94-mile pipeline interconnecting the Sabine Pass LNG terminal with a number of large interstate pipelines (the "Creole Trail Pipeline").

Approximately one-half of the receiving capacity at the Sabine Pass LNG terminal is contracted to two multinational energy companies. The other half is held by Sabine Pass Liquefaction for use in connection with the Liquefaction Project. One of our wholly owned subsidiaries, Cheniere Marketing, LLC ("Cheniere Marketing"), markets LNG on its own behalf, and through a series of agreements, has the right to utilize the regasification capacity held by Sabine Pass Liquefaction during the construction phase of the Liquefaction Project. Cheniere Marketing also holds a 104 million MMBtu per year LNG sale and purchase agreement ("SPA") with Sabine Pass Liquefaction under which it has the right to purchase LNG from Sabine Pass Liquefaction for a tiered incentive-based fee.

We are also in various stages of developing other projects, including LNG terminal liquefaction and pipeline facilities, each of which, among other things, will require acceptable commercial and financing arrangements before we make a final investment decision.

25

Overview of Significant Events

Our significant accomplishments since January 1, 2013 and through the filing date of this Form 10-Q include the following:  

• Sabine Pass Liquefaction issued an aggregate principal amount of $2.0 billion of 5.625% Senior Secured Notes due 2021 (the "2021 Sabine Pass Liquefaction Senior Notes") and an aggregate principal amount of $1.0 billion of 5.625% Senior Secured Notes due 2023 (the "2023 Sabine Pass Liquefaction Senior Notes"). Net proceeds from those offerings are intended to be used to pay a portion of the capital costs incurred in connection with the construction of the Liquefaction Project;

• Cheniere Partners sold 17.6 million common units to institutional investors for net proceeds, after deducting expenses, of $372.4 million, which includes the general partner's proportionate capital contribution of approximately $7.4 million. Cheniere Partners used the proceeds from that offering to purchase the Creole Trail Pipeline Business;

• Sabine Pass Liquefaction entered into four credit facilities totaling $5.9 billion (collectively, the "2013 Liquefaction Credit Facilities") to be used for costs associated with the construction of Train 1 through Train 4 of the Liquefaction Project;

• Sabine Pass Liquefaction issued a notice to proceed to Bechtel Oil, Gas and Chemicals, Inc. ("Bechtel") under the lump sum turnkey contract for the engineering, procurement and construction of Train 3 and Train 4 (the "EPC Contract (Train 3 and Train 4)");

• Sabine Pass Liquefaction entered into the Centrica plc ("Centrica") SPA that commences upon the date of first commercial delivery for Train 5 and includes an annual contract quantity of 91.25 million MMBtu of LNG with a fixed fee of $3.00 per MMBtu, equating to expected annual contracted cash flow from fixed fees of $274.0 million;

• We sold our ownership interests in the Creole Trail Pipeline Business to Cheniere Partners for $480.0 million and were reimbursed $13.9 million for certain expenditures incurred prior to the closing date.  Concurrent with the Creole Trail Pipeline Business sale closing, we acquired 12.0 million Class B units from Cheniere Partners for aggregate consideration of $180.0 million pursuant to a unit purchase agreement between Cheniere Partners and Cheniere Class B Units Holdings, LLC, our wholly owned subsidiary.  As a result of the two transactions, we received net cash of $313.9 million; and

• CTPL entered into a $400.0 million term loan credit facility to fund capital expenditures on the Creole Trail Pipeline and for general business purposes.

Liquidity and Capital Resources

Although consolidated for financial reporting, Cheniere, Sabine Pass LNG and Cheniere Partners operate with independent capital structures. We expect the cash needs for Sabine Pass LNG's operating activities for at least the next twelve months will be met through its operating cash flows and existing unrestricted cash. We expect the cash needs for Cheniere Partners' operating activities and capital expenditures for at least the next twelve months will be met through operating cash flows from Sabine Pass LNG, existing unrestricted cash, project debt and equity financings. We expect the cash needs of Cheniere's operating activities and capital expenditures for at least the next twelve months will be met by utilizing existing unrestricted cash, management fees from Cheniere Partners and its subsidiaries, distributions from our investment in Cheniere Partners and operating cash flows from our LNG and natural gas marketing business.

The following table presents (in thousands) Cheniere's restricted and unrestricted cash and cash equivalents for each portion of our capital structure as of September 30, 2013. All restricted and unrestricted cash and cash equivalents held by Cheniere Partners and Sabine Pass LNG are considered restricted as to usage or withdrawal by Cheniere:

	Sabine Pass LNG			Cheniere Partners			Other Cheniere		Consolidated Cheniere
Cash and cash equivalents	$	—		$	—		$	374,164	$	374,164
Restricted cash and cash equivalents	139,591		(1)	1,238,740		(2)	28,472		1,406,803
Total	$	139,591		$	1,238,740		$	402,636	$	1,780,967

(1) All cash and cash equivalents presented above for Sabine Pass LNG are considered restricted to us, but $10.5 million is considered unrestricted for Sabine Pass LNG.

(2) All cash and cash equivalents presented above for Cheniere Partners are considered restricted to us, but $339.9 million is considered unrestricted for Cheniere Partners, including the $10.5 million considered unrestricted for Sabine Pass LNG.

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As of September 30, 2013, we had unrestricted cash and cash equivalents of $374.2 million available to Cheniere. In addition, we had consolidated restricted cash and cash equivalents of $1,406.8 million (which included cash and cash equivalents available to Cheniere Partners, in which we own a 57.9% interest, and Sabine Pass LNG) designated for the following purposes: $798.6 million for the Liquefaction Project; $75.0 million for the Creole Trail Pipeline and $329.4 million for Cheniere Partners' working capital; $164.8 million for interest payments related to the Sabine Pass LNG Senior Notes and CTPL Credit Facility described below; $10.5 million for Sabine Pass LNG's working capital; and $28.5 million for other restricted purposes.

Cheniere Partners

Our ownership interest in the Sabine Pass LNG terminal is held through Cheniere Partners. We own approximately 57.9% of Cheniere Partners in the form of 12.0 million common units, 45.3 million Class B units, 135.4 million subordinated units and a 2% general partner interest. Cheniere Partners owns a 100% interest in Sabine Pass LNG, which is operating the regasification facilities at the Sabine Pass LNG terminal, a 100% interest in Sabine Pass Liquefaction, which is constructing the Liquefaction Project and a 100% interest in CTPL, which is operating and modifying the Creole Trail Pipeline in order to enable bi-directional natural gas flow.

We receive quarterly equity distributions from Cheniere Partners, and we receive management fees for managing Sabine Pass LNG, Sabine Pass Liquefaction, CTPL and Cheniere Partners. For the nine months endedSeptember 30, 2013, we received $15.3 million in distributions on our common units, no cash distributions on our subordinated units or Class B units and $1.3 million in distributions on our general partner interest. During the nine months endedSeptember 30, 2013, we received fees of $6.4 million, $55.3 million, $8.5 million and $0.1 million under our management agreements with Sabine Pass LNG, Sabine Pass Liquefaction, Cheniere Partners and CTPL, respectively.

Cheniere Partners' common unit and general partner distributions are being funded from accumulated operating surplus. We have not received distributions on our subordinated units since the distribution made with respect to the quarter ended March 31, 2010. Cheniere Partners will not make distributions on our subordinated units unless it generates additional cash flow from Sabine Pass LNG's excess capacity or new business. Therefore, distributions to us on our subordinated units and conversion of the subordinated units into common units will depend upon the future business development of Cheniere Partners. We expect that additional cash flows generated by the Liquefaction Project or other new Cheniere Partners' business would be used to make quarterly distributions on our subordinated units before any increase in distributions to the common unitholders.

Our Class B units are subject to conversion, mandatorily or at our option under specified circumstances, into a number of common units based on the then-applicable conversion value of the Class B units. 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 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. The Class B units will mandatorily convert into common units on the first business day following the record date with respect to Cheniere Partners' first distribution (the "Mandatory Conversion Date") after the earlier of the substantial completion date of Train 3 or August 9, 2017, although if a notice to proceed is given to Bechtel for Train 3 prior to August 9, 2017, the Mandatory Conversion Date will be the substantial completion date of Train 3. The notice to proceed was given to Bechtel on May 28, 2013. We currently expect the substantial completion date of Train 3 to occur before March 31, 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.

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We have entered into a services agreement with Cheniere Partners pursuant to which Cheniere Partners pays us a quarterly non-accountable overhead reimbursement charge of $2.8 million (adjusted for inflation) for providing various general and administrative services for Cheniere Partners' benefit. In addition, Cheniere Partners reimburses us for all audit, tax, legal and finance fees incurred by us that are necessary to perform the services under the agreement.

Cheniere Holdings

Cheniere Energy Partners LP Holdings, LLC ("Cheniere Holdings") has filed a registration statement with the U.S. Securities and Exchange Commission relating to its proposed initial public offering of common shares. Cheniere Holdings' only business will consist of owning limited partner units of Cheniere Partners currently owned by us. We will ultimately receive the net proceeds from the initial public offering of common shares of Cheniere Holdings, which we intend to use for the development of our existing assets, future projects and general corporate purposes.  We anticipate continuing to own at least 80% of Cheniere Holdings after the offering.

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 terminal use agreements ("TUAs"), under which Sabine Pass LNG’s customers are required to pay fixed monthly fees, whether or not they use the LNG terminal. Capacity reservation fee TUA payments are made by Sabine Pass LNG's third-party TUA customers as follows: 

• Total Gas & Power North America, Inc. ("Total") has reserved approximately 1.0 Bcf/d of regasification capacity and is obligated to make monthly capacity payments to Sabine Pass LNG aggregating approximately $125 million annually for 20 years that commenced April 1, 2009. Total, S.A. has guaranteed Total’s obligations under its TUA of approximately $2.5 billion, subject to certain exceptions; 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 Sabine Pass LNG aggregating approximately $125 million annually for 20 years that commenced July 1, 2009. 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 Sabine Pass Liquefaction. Sabine Pass Liquefaction is obligated to make monthly capacity payments to Sabine Pass LNG aggregating approximately $250 million annually, continuing until at least 20 years after Sabine Pass Liquefaction delivers its first commercial cargo at Sabine Pass Liquefaction's facilities under construction, which may occur as early as late 2015. Cheniere Energy Investments, LLC ("Cheniere Investments"), a wholly owned subsidiary of Cheniere Partners, Sabine Pass Liquefaction and Sabine Pass LNG entered into a terminal use rights assignment and agreement ("TURA") pursuant to which Cheniere Investments has the right to use Sabine Pass Liquefaction's reserved capacity under the TUA and has the obligation to make the monthly capacity payments required by the TUA to Sabine Pass LNG. In an effort to utilize Cheniere Investments’ reserved capacity under its TURA during construction of the Liquefaction Project, Cheniere Marketing, LLC ("Cheniere Marketing"), a wholly owned subsidiary of Cheniere, has entered into an amended and restated variable capacity rights agreement ("amended and restated VCRA") pursuant to which Cheniere Marketing is obligated to pay Cheniere Investments 80% of the expected gross margin of each cargo of LNG that Cheniere Marketing arranges for delivery to the Sabine Pass LNG terminal. The revenue earned by Sabine Pass LNG from the capacity payments made under the TUA, the loss incurred by Cheniere Investments under the TURA and the revenue earned by Cheniere Investments under the VCRA are eliminated upon consolidation of our financial statements. Cheniere Partners has guaranteed the obligations of Sabine Pass Liquefaction under its TUA and the obligations of Cheniere Investments under the TURA.

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In September 2012, Sabine Pass Liquefaction entered into a partial TUA assignment agreement with Total, whereby Sabine Pass Liquefaction will progressively gain access to Total's capacity and other services provided under Total's TUA with Sabine Pass LNG.  This agreement will provide Sabine Pass Liquefaction with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to accommodate the development of Train 5 and Train 6, provide increased flexibility in managing LNG cargo loading and unloading activity starting with the commencement of commercial operations of Train 3, and permit Sabine Pass Liquefaction to more flexibly manage its LNG storage capacity with the commencement of Train 1. Notwithstanding any arrangements between Total and Sabine Pass Liquefaction, payments required to be made by Total to Sabine Pass LNG will continue to be made by Total to Sabine Pass LNG in accordance with its TUA.

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

Liquefaction Facilities

The Liquefaction Project is being developed at the Sabine Pass LNG terminal adjacent to the existing regasification facilities. We plan to construct up to six Trains, which are in various stages of development. In August 2012, we commenced construction of Train 1 and Train 2 and the related new facilities needed to treat, liquefy, store and export natural gas. In May 2013, we commenced construction of Train 3 and Train 4 and the related facilities. We are developing Train 5 and Train 6 and commenced the regulatory approval process for these Trains in February 2013. Trains 1 through 4 are being designed, constructed and commissioned by Bechtel using the ConocoPhillips Optimized Cascade® technology, a proven technology deployed in numerous LNG projects around the world. Sabine Pass Liquefaction has entered into a lump sum turnkey contract for the engineering, procurement and construction of Train 1 and Train 2 (the "EPC Contract (Train 1 and Train 2)") and the EPC Contract (Train 3 and Train 4) with Bechtel in November 2011 and December 2012, respectively, under which Bechtel charges a lump sum for all work performed and generally bears project cost risk.

Cheniere Partners has received authorization from the Federal Energy Regulatory Commission (the "FERC") to site, construct and operate Train 1, Train 2, Train 3 and Train 4. Cheniere Partners has also filed an application with the FERC for the approval to construct Train 5 and Train 6. The Department of Energy (the "DOE") has granted Sabine Pass Liquefaction an order authorizing the export of up to the equivalent of 16 mtpa (approximately 803 Bcf/yr) of LNG to all nations with which trade is permitted for a 20-year term beginning on the earlier of the date of first export from Train 1 or August 7, 2017. The DOE further issued two orders authorizing the export of an additional 189.3 Bcf/yr in total of domestically produced LNG from the Sabine Pass LNG terminal to FTA countries providing for national treatment for trade in natural gas for a 20-year term.  One order authorized the export of 101 Bcf /yr of domestically produced LNG pursuant to the SPA with Total, beginning on the earlier of the date of first export from Train 5 or July 11, 2021; and the other order authorized the export of 88.3 Bcf/yr of domestically produced LNG pursuant to the SPA with Centrica, beginning on the earlier of the date of first export from Train 5 or July 12, 2021.

As of September 30, 2013, the overall project completion for Train 1 and Train 2 of the Liquefaction Project was approximately 45%, which is ahead of the contractual schedule. As of September 30, 2013, the overall project completion for Train 3 and Train 4 of the Liquefaction Project was approximately 10%, which is ahead of the contractual schedule. Based on our current construction schedule, we anticipate that Train 1 will produce LNG as early as late 2015, with commercial operations expected to commence in February 2016, and Train 2, Train 3 and Train 4 are expected to commence operations on a staggered basis thereafter.

Customers

Sabine Pass Liquefaction has entered into six fixed price, 20-year SPAs with third parties that in the aggregate equate to approximately 19.75 mtpa of LNG, which represents approximately 88% of the anticipated nominal production capacity of Train 1 through Train 5. Under the SPAs, the customers will purchase LNG from us on an FOB basis 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.

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To date, Sabine Pass Liquefaction has the following third-party SPAs:

• BG Gulf Coast LNG, LLC ("BG") has entered into an SPA (the "BG SPA") that commences upon the date of first commercial delivery for Train 1 and includes an annual contract quantity of 182,500,000 MMBtu of LNG with a fixed fee of $2.25 per MMBtu and includes additional annual contract quantities of 36,500,000 MMBtu, 34,000,000 MMBtu, and 33,500,000 MMBtu upon the date of first commercial delivery for Train 2, Train 3 and Train 4, respectively, with a fixed fee of $3.00 per MMBtu. The total expected annual contracted cash flow from BG from fixed fees is approximately $723 million. In addition, Sabine Pass Liquefaction has agreed to make up to 500,000 MMBtu/d of LNG available to BG to the extent that Train 1 becomes commercially operable prior to the beginning of the first delivery window with a fixed fee of $2.25 per MMBtu, if produced. The obligations of BG are guaranteed by BG Energy Holdings Limited, a company organized under the laws of England and Wales.

• Gas Natural Aprovisionamientos SDG S.A.("Gas Natural Fenosa") has entered into an SPA (the "Gas Natural Fenosa SPA") that commences upon the date of first commercial delivery for Train 2 and includes an annual contract quantity of 182,500,000 MMBtu of LNG with a fixed fee of $2.49 per MMBtu, equating to expected annual contracted cash flow from fixed fees of approximately $454 million. In addition, Sabine Pass Liquefaction has agreed to make up to 285,000 MMBtu/d of LNG available to Gas Natural Fenosa to the extent that Train 2 becomes commercially operable prior to the beginning of the first delivery window with a fixed fee of $2.49 per MMBtu, if produced. The obligations of Gas Natural Fenosa are guaranteed by Gas Natural SDG S.A., a company organized under the laws of Spain.

• Korea Gas Corporation ("KOGAS") has entered into an SPA (the "KOGAS SPA") that commences upon the date of first commercial delivery for Train 3 and includes an annual contract quantity of 182,500,000 MMBtu of LNG with a fixed fee of $3.00 per MMBtu, equating to expected annual contracted cash flow from fixed fees of approximately $548 million. KOGAS is organized under the laws of the Republic of Korea.

• GAIL (India) Limited ("GAIL") has entered into an SPA (the "GAIL SPA") that commences upon the date of first commercial delivery for Train 4 and includes an annual contract quantity of 182,500,000 MMBtu of LNG with a fixed fee of $3.00 per MMBtu, equating to expected annual contracted cash flow from fixed fees of approximately $548 million. GAIL is organized under the laws of India.

• Total has entered into an SPA (the "Total SPA") that commences upon the date of first commercial delivery for Train 5 and includes an annual contract quantity of 104,750,000 MMBtu of LNG with a fixed fee of $3.00 per MMBtu, equating to expected annual contracted cash flow from fixed fees of approximately $314 million. The obligations of Total are guaranteed by Total S.A., a company organized under the laws of France.

• Centrica has entered into an SPA (the "Centrica SPA") that commences upon the date of first commercial delivery for Train 5 and includes an annual contract quantity of 91,250,000 MMBtu of LNG with a fixed fee of $3.00 per MMBtu, equating to expected annual contracted cash flow from fixed fees of approximately $274 million. Centrica is organized under the laws of England and Wales.

In aggregate, the fixed fee portion to be paid by these customers is approximately $2.3 billion annually for Train 1 through Train 4, and $2.9 billion annually if we make a positive final investment decision with respect to Train 5, with the applicable fixed fees starting from the commencement of commercial operations for the applicable Train. These fixed fees equal approximately $411 million, $564 million, $650 million, $648 million and $588 million for each respective Train.

In addition, Cheniere Marketing has entered into an SPA with Sabine Pass Liquefaction to purchase, at Cheniere Marketing's option, up to 104,000,000 MMBtu/yr of LNG produced from Train 1 through Train 4. Sabine Pass Liquefaction has the right each year during the term to reduce the annual contract quantity based on its assessment of how much LNG it can produce in excess of that required for other customers. Cheniere Marketing may purchase incremental LNG volumes at a price of 115% of Henry Hub: plus up to $3.00 per MMBtu for the most profitable 36,000,000 MMBtu of cargoes sold each year by Cheniere Marketing; and then 20% of net profits of the remaining 68,000,000 MMBtu sold each year by Cheniere Marketing.

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Construction

In November 2011, Sabine Pass Liquefaction entered into the EPC Contract (Train 1 and Train 2) with Bechtel. Sabine Pass Liquefaction issued a notice to proceed with construction under the EPC Contract (Train 1 and Train 2) in August 2012. In December 2012, Sabine Pass Liquefaction entered into the EPC Contract (Train 3 and Train 4) with Bechtel. Sabine Pass Liquefaction issued a notice to proceed with construction under the EPC Contract (Train 3 and Train 4) in May 2013. The Trains are in various stages of development, as described above.

The total contract price of the EPC Contract (Train 1 and Train 2) and the total contract price of the EPC Contract (Train 3 and Train 4) is approximately $4.0 billion and $3.8 billion, respectively, reflecting amounts incurred under change orders through September 30, 2013. Total expected capital costs for Train 1 through Train 4 are estimated to be between $9.0 billion and $10.0 billion before financing costs, and between $12.0 billion and $13.0 billion after financing costs, including in each case estimated owner's costs and contingencies. Sabine Pass Liquefaction's Trains will require significant amounts of capital to construct and operate and are subject to risks and delays in completion.

The liquefaction technology to be employed under the EPC Contracts is the ConocoPhillips Optimized Cascade® Process, which was first used at the ConocoPhillips Petroleum Kenai plant built by Bechtel in 1969 in Kenai, Alaska. Bechtel has since designed and/or constructed LNG facilities using the ConocoPhillips Optimized Cascade® technology in Angola, Australia, Egypt, Equatorial Guinea and Trinidad. The design and technology has been proven in over four decades of operation.

We currently expect that Sabine Pass Liquefaction's capital resources requirements with respect to Train 1 through Train 4 will be financed through borrowings, equity contributions from us and cash flows under the SPAs. We believe that with the net proceeds of borrowings and unfunded commitments under the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction will have adequate financial resources available to complete Train 1 through Train 4 and to meet its currently anticipated capital, operating and debt service requirements. We currently project that Sabine Pass Liquefaction will generate cash flow by late 2015, when Train 1 is anticipated to achieve initial LNG production.

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, including Natural Gas Pipeline Company of America, Transcontinental Gas Pipeline Corporation, Tennessee Gas Pipeline Company, Florida Gas Transmission Company, Texas Eastern Gas Transmission, and Trunkline Gas Company, as well as the intrastate pipeline system of Bridgeline Holdings, L.P. Sabine Pass Liquefaction has entered into transportation precedent agreements to secure firm pipeline transportation capacity with CTPL and two other pipeline companies.

CTPL will need to obtain the FERC's approval prior to making any modifications to the Creole Trail Pipeline as it is a regulated, interstate pipeline. An application for authorization to construct, own, operate and maintain certain new facilities in order to enable bi-directional natural gas flow on the Creole Trail Pipeline system was submitted to the FERC by CTPL in April 2012. In February 2013, the FERC approved the proposed project, and in October 2013, the FERC issued an order denying petitioner's request for rehearing and stay of the approval. In addition, in November 2013, CTPL received approval from the Louisiana Department of Environmental Quality for the proposed modifications to the Creole Trail Pipeline system. We estimate the capital costs to modify the Creole Trail Pipeline will be approximately $100 million. The modifications are expected to be in service in time for the commissioning and testing of Train 1 and Train 2.

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Capital Resources

Senior Secured Notes

We currently have four series of senior notes outstanding:

•$1,665.5 million of 7.50% Senior Secured Notes due 2016 issued by Sabine Pass LNG (the "2016 Notes");

•$420.0 million of 6.50% Senior Secured Notes due 2020 issued by Sabine Pass LNG (the "2020 Notes" and

collectively with the 2016 Notes, the "Sabine Pass LNG Senior Notes");

•$2,000.0 million of the 2021 Sabine Pass Liquefaction Senior Notes; and

•$1,000.0 million of the 2023 Sabine Pass Liquefaction Senior Notes (collectively with the 2021 Sabine Pass

Liquefaction Notes, the "Sabine Pass Liquefaction Senior Notes").

Interest on the 2016 Notes is payable semi-annually in arrears on May 30 and November 30 of each year, interest on the 2020 Notes is payable semi-annually in arrears on May 1 and November 1 of each year, interest on the 2021 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on February 1 and August 1 of each year and interest on the 2023 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on April 15 and October 15 of each year. Subject to permitted liens, the Sabine Pass LNG Senior Notes are secured on a pari passu first-priority basis by a security interest in all of Sabine Pass LNG's equity interests and substantially all of Sabine Pass LNG's operating assets, and the Sabine Pass Liquefaction Senior Notes are secured on a first-priority basis by a security interest in all of the membership interests in Sabine Pass Liquefaction and substantially all of Sabine Pass Liquefaction's assets.

Sabine Pass LNG may redeem some or all of its 2016 Notes at any time, and from time to time, at the redemption prices specified in the indenture governing the 2016 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may redeem some or all of the 2020 Notes at any time on or after November 1, 2016 at fixed redemption prices specified in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may also redeem some or all of the 2020 Notes at any time prior to November 1, 2016 at a "make-whole" price set forth in the indenture, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, Sabine Pass LNG may redeem up to 35% of the aggregate principal amount of the 2020 Notes at a redemption price of 106.5% of the principal amount of the 2020 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 Sabine Pass LNG redeems the 2020 Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Notes originally issued remains outstanding after the redemption.

At any time prior to November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction may redeem all or a part of the Sabine Pass Liquefaction Senior Notes, at a redemption price equal to the "make-whole" price set forth in the Indenture, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass Liquefaction also may at any time on or after November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, redeem the Sabine Pass Liquefaction Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the Sabine Pass Liquefaction Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

Under the indentures governing the Sabine Pass LNG Senior Notes, except for permitted tax distributions, Sabine Pass LNG 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 indentures governing the Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction may not make any distributions until, among other requirements, substantial completion of Train 1 and Train 2 has occurred, deposits are made into debt service reserve accounts and a debt service coverage ratio for the prior 12-month period and a projected debt service coverage ratio for the upcoming 12-month period of 1.25:1.00 are satisfied.

Sabine Pass Liquefaction 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 Sabine Pass Liquefaction, including the Sabine Pass Liquefaction Senior Notes and the 2013 Liquefaction Credit Facilities described below.

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2013 Liquefaction Credit Facilities

Sabine Pass Liquefaction has four credit facilities aggregating $5.9 billion, which will be used to fund a portion of the costs of developing, constructing and placing into operation Train 1 through Train 4 of the Liquefaction Project. The principal of the loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing with the earlier of the last day of the first full calendar quarter after the Train 4 completion date and September 30, 2018. Loans under the 2013 Liquefaction Credit Facilities bear interest at a variable rate per annum equal to, at Sabine Pass Liquefaction's election, the London Interbank Offered Rate ("LIBOR"), plus the applicable margin. The applicable margins for LIBOR loans prior to, and after, the completion of Train 4 range from 2.3% to 3.0 % and 2.3% to 3.25%, respectively, depending on the applicable 2013 Liquefaction Credit Facility. The 2013 Liquefaction Credit Facilities also require Sabine Pass Liquefaction to pay a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitments. Interest on LIBOR loans and the commitment fees are due and payable at the end of each LIBOR period.

2012 Liquefaction Credit Facility

In July 2012, Sabine Pass Liquefaction entered into a construction/term loan facility in an amount up to $3.6 billion (the "2012 Liquefaction Credit Facility"), which was available to Sabine Pass Liquefaction in four tranches solely to fund Liquefaction Project costs for Train 1 and Train 2, the related debt service reserve account up to an amount equal to six months of scheduled debt service and the return of equity and affiliate subordinated debt funding to Cheniere or its affiliates up to an amount that would result in senior debt being no more than 65% of our total capitalization. Borrowings under the 2012 Liquefaction Credit Facility were based on LIBOR plus 3.50% during construction and 3.75% during operations. Sabine Pass Liquefaction was also required to pay commitment fees on the undrawn amount. The 2012 Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities.

CTPL Credit Facility

CTPL has a $400 million term loan facility (the "CTPL Credit Facility"), which will be used to fund modifications to the Creole Trail Pipeline and for general business purposes. Loans under the CTPL Credit Facility bear 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 under the CTPL Credit Facility is 3.25%. The CTPL Credit Facility matures in 2017 when the full amount of the outstanding principal obligations must be repaid.

Corpus Christi LNG Terminal

Liquefaction Facilities

In September 2011, we formed Corpus Christi Liquefaction, LLC ("Corpus Christi Liquefaction") to develop an LNG terminal near Corpus Christi on over 1,000 acres of land that we own or control. As currently contemplated, the proposed Corpus Christi Liquefaction LNG terminal would be designed for up to three Trains with expected aggregate nominal production capacity up to 15 mtpa of LNG, have three LNG storage tanks with capacity of 10.1 Bcfe and two docks that can accommodate vessels with capacity of up to 265,000 cubic meters (the "Corpus Liquefaction Project").

In December 2011, Corpus Christi Liquefaction received approval from the FERC to begin the National Environmental Policy Act ("NEPA") pre-filing process required to seek authorization to commence construction of the Corpus Liquefaction Project. In August 2012, Corpus Christi Liquefaction filed an application with the FERC for authorization to site, construct and operate the Corpus Liquefaction Project. Simultaneously, Cheniere Marketing filed an application with the DOE to export up to 15 mtpa of domestically produced LNG to free trade agreement ("FTA") and non-FTA countries from the proposed Corpus Liquefaction Project. In October 2012, the DOE granted Cheniere Marketing authority to export 15 mtpa of domestically produced LNG to FTA countries from the proposed Corpus Liquefaction Project.

We will contemplate making a final investment decision to commence construction of the Corpus Liquefaction Project based upon, among other things, entering into acceptable commercial arrangements, receiving regulatory authorization from the FERC to construct and operate the liquefaction assets, securing pipeline transportation of natural gas to the Corpus Liquefaction Project and obtaining adequate financing to construct the facility.

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Pipeline Facilities

In conjunction with the Corpus Liquefaction Project, we filed an application with the FERC in August 2012 for authorization to site, construct and operate 23 miles of 48" pipeline that would interconnect the Corpus Liquefaction Project with approximately 3.25 Bcf/d of natural gas interconnect capacity (the "Corpus Christi Pipeline"). The pipeline is designed to transport 2.25 Bcf/d of feed and fuel gas required by the Corpus Liquefaction Project from the existing intra- and interstate natural gas pipeline grid.

We will contemplate making a final investment decision to commence construction of the Corpus Christi Pipeline based upon, among other things, a final investment decision of the Corpus Liquefaction Project, receiving regulatory authorization from the FERC to construct and operate the pipeline and obtaining adequate financing.

Other LNG Terminal Sites and Facilities

We continue to evaluate, and may develop, additional sites that we believe may be commercially desirable locations for LNG terminals and other facilities.

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, assist Cheniere Investments in negotiating with potential customers to utilize regasification capacity at the Sabine Pass LNG terminal to which it has access under the TURA during construction of the Liquefaction Project, and to assist Sabine Pass Liquefaction and Corpus Christi Liquefaction in negotiating LNG SPAs with potential long term customers.

Cheniere Marketing has been purchasing, transporting and unloading commercial LNG cargoes into the Sabine Pass LNG terminal and has used trading strategies intended to maximize margins on these cargoes. In addition, Cheniere Marketing has continued to enter into various business relationships to facilitate purchasing and selling commercial LNG cargoes.

In an effort to utilize Cheniere Investments’ reserved capacity under its TURA during construction of the Liquefaction Project, Cheniere Marketing has entered into the VCRA pursuant to which Cheniere Marketing is obligated to pay Cheniere Investments 80% of the expected gross margin of each cargo of LNG that Cheniere Marketing arranges for delivery to the Sabine Pass LNG terminal. During the term of the VCRA, Cheniere Marketing is responsible for the payment of taxes and new regulatory costs under the Sabine Pass Liquefaction TUA. Cheniere has guaranteed all of Cheniere Marketing's payment obligations under the VCRA.

As described above, Cheniere Marketing has entered into an SPA to purchase, at Cheniere Marketing's option, up to 104,000,000 MMBtu of LNG per annum produced from Train 1 through Train 4. In June 2013, Cheniere Marketing entered into three LNG vessel charters in order to secure shipping capacity for the export of LNG from Sabine Pass Liquefaction's Train 1 through Train 4 under Cheniere Marketing's SPA.

The accounting treatment for LNG inventory differs from the treatment for derivative positions such that the economics of Cheniere Marketing's activities are not transparent in our consolidated financial statements until all LNG inventory is sold and all derivative positions are settled. Our LNG inventory is recorded as an asset at cost and is subject to lower of cost or market ("LCM") adjustments at the end of each reporting period. The LCM adjustment market price is based on period-end natural gas spot prices, and any gain or loss from an LCM adjustment is recorded in our earnings at the end of each period. Revenue and cost of goods sold are not recognized in our earnings until the LNG is sold. Generally, our unrealized derivatives positions at the end of each period extend into the future to hedge future sales of our LNG inventory or to take market positions and hedge exposure associated with LNG and natural gas. These positions are measured at fair value, and we record the gains and losses from the change in their fair value currently in earnings. Thus, earnings from changes in the fair value of our derivatives may not be offset by losses from LCM adjustments to our LNG inventory because the LCM adjustments that may be made to LNG inventory are based on period-end spot prices that are different from the time periods of the prices used to determine the fair value of our derivatives. Any losses from changes in the fair value of our derivatives will not be offset by gains until the LNG is actually sold.

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Corporate and Other Activities

We are required to maintain corporate general and administrative functions to serve our business activities described above. 

Sources and Uses of Cash

The following table summarizes (in thousands) the sources and uses of our cash and cash equivalents for the nine months endedSeptember 30, 2013 and 2012. The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, that are referred to elsewhere in this report. Additional discussion of these items follows the table. 

	Nine Months Ended September 30,
	2013			2012
Sources of cash and cash equivalents
Proceeds from debt issuances and credit facilities	$	3,504,478		$	100,000
Sale of common units by Cheniere Partners	364,775			205,174
Sale of common stock, net	274			1,200,717
Sale of Class B Units by Cheniere Partners	—			887,563
Excess tax benefit from stock-based compensation	2,070			—
Total sources of cash and cash equivalents	3,871,597			2,393,454
Uses of cash and cash equivalents
LNG terminal costs, net	(2,448,690		)	(871,167		)
Investment in restricted cash and cash equivalents, net of uses of restricted cash and cash equivalents	(716,122		)	(72,553		)
Debt issuance and deferred financing costs	(235,250		)	(210,828		)
Repayments and prepayments of debt	(100,000		)	(776,514		)
Payments related to tax withholdings for stock-based compensation	(89,137		)	(20,414		)
Distributions to non-controlling interest	(50,046		)	(24,628		)
Operating cash flow	(22,303		)	(104,979		)
Investment in Cheniere Partners	(11,122		)	(534,940		)
Other	(26,474		)	(21,596		)
Total uses of cash and cash equivalents	(3,699,144		)	(2,637,619		)
Net increase (decrease) in cash and cash equivalents	172,453			(244,165		)
Cash and cash equivalents—beginning of period	201,711			459,160
Cash and cash equivalents—end of period	$	374,164		$	214,995

Proceeds from the Debt Issuances and Credit Facilities

In February 2013 and April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $2.0 billion, before premium, of the 2021 Sabine Pass Liquefaction Senior Notes. In April 2013, Sabine Pass Liquefaction also issued $1.0 billion of the 2023 Sabine Pass Liquefaction Senior Notes. Net proceeds from those offerings are intended to be used to pay a portion of the capital costs incurred in connection with the construction of the Liquefaction Project. In May 2013, Sabine Pass Liquefaction closed the 2013 Liquefaction Credit Facilities aggregating $5.9 billion. The 2013 Liquefaction Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation the first four Trains of the Liquefaction Project. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent. Also in May 2013, CTPL entered into the $400.0 million CTPL Credit Facility, which will be used to fund modifications to the Creole Trail Pipeline and for general business purposes.

In July 2012, Sabine Pass Liquefaction entered into the $3.6 billion 2012 Liquefaction Credit Facility with a syndicate of lenders. The 2012 Liquefaction Credit Facility was intended to be used to fund a portion of the costs of developing, constructing and placing into operation Train 1 and Train 2 of the Liquefaction Project. In May 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities and $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full.

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Sale of Common Units by Cheniere Partners

The proceeds from the sale of partnership common units in the nine months ended September 30, 2013 related to a February 2013 common unit purchase agreement with institutional investors to sell 17.6 million common units for net proceeds, after deducting expenses, of $365.0 million. Cheniere Partners used the proceeds from this offering to purchase the Creole Trail Pipeline Business.

In September 2012, Cheniere Partners sold 8.0 million common units in an underwritten public offering at a price of $25.07 per common unit for net cash proceeds of $194.0 million. In addition, during the nine months ended September 30, 2012, Cheniere Partners sold 0.5 million common units for net cash proceeds of $11.1 million under the at-the-market program initiated in January 2011.

Sale of Common Stock, net

In March 2012, we sold 24.2 million shares of Cheniere common stock in an underwritten public offering for net cash proceeds of approximately $351.9 million. In June 2012, we used a portion of the net proceeds from this offering to repay in full $273.9 million of loans originally incurred in 2008. In May 2012, we sold 31.0 million shares of Cheniere common stock pursuant to a stock purchase agreement for net proceeds of $468.1 million, which has been used, along with cash on hand, to purchase $500 million of Class B units from Cheniere Partners. In July 2012, we sold 28.0 million shares of Cheniere common stock in an underwritten public offering for net cash proceeds of $380.3 million. We used a portion of the net proceeds from the offering to repay our Convertible Senior Unsecured Notes due August 1, 2012, and used the remaining amount for capital expenditures on the Creole Trail Pipeline and general corporate purposes.

Sale of Class B Units by Cheniere Partners

During the nine months ended September 30, 2012, Cheniere Partners issued and sold an aggregate of 66.7 million Class B units to Blackstone CQP Holdco LP at a price of $15.00 per Class B unit, resulting in total net proceeds of $887.6 million. Proceeds from the Class B unit sales are being used to fund the equity portion of the costs of developing, constructing and placing into service the Liquefaction Project.

LNG Terminal Costs, net

LNG terminal costs, net primarily related to the construction of Train 1 through Train 4 of the Liquefaction Project. In June 2012, we began capitalizing costs associated with Train 1 and Train 2 of the Liquefaction Project, and in May 2013, we began capitalizing costs associated with Train 3 and Train 4 of the Liquefaction Project.

Investment in Restricted Cash and Cash Equivalents, Net of Uses of Restricted Cash and Cash Equivalents

In the nine months endedSeptember 30, 2013, we invested $716.1 million in restricted cash and cash equivalents. This investment in restricted cash and cash equivalents is primarily a result of the 3,182.7 million investment in restricted cash and cash equivalents primarily related to the net proceeds from the Sabine Pass Liquefaction Senior Notes, the CTPL Credit Facility and the 2013 Liquefaction Credit Facilities. This investment in restricted cash and cash equivalents was partially offset by the use of $2,466.6 million of restricted cash and cash equivalents primarily related to the construction of the Liquefaction Project.

Debt Issuance and Deferred Financing Costs

Debt issuance and deferred financing costs in the nine months ended September 30, 2013 resulted from amounts paid by Sabine Pass Liquefaction related to the 2013 Liquefaction Credit Facilities and the Sabine Pass Liquefaction Senior Notes and amounts paid by CTPL related to the CTPL Credit Facility. Debt issuance and deferred financing costs in the nine months ended September 30, 2012 resulted from amounts paid by Sabine Pass Liquefaction upon the closing of the 2012 Liquefaction Credit Facility.

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Repayments and Prepayments of Debt

During the nine months ended September 30, 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities described above and the $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full. In January 2012, we used a portion of the net proceeds from the public offering of Cheniere common stock in December 2011 to repay in full loans originally incurred in 2007. In June 2012, we used a portion of the net proceeds from the public offering of Cheniere common stock in March 2012 to repay in full loans originally incurred in 2008.

Payments Related to Tax Withholdings for Stock-based Compensation

During the nine months ended September 30, 2013, employees tendered $89.1 million of shares to satisfy their tax withholding obligations primarily in connection with employee stock vestings under the 2011-2013 Bonus plan. We designated these shares as treasury shares.

In the nine months ended September 30, 2012, employees tendered $20.4 million of shares to satisfy their tax withholding obligations primarily in connection with the vesting of employee stock awards under the long-term commercial bonus pool when Sabine Pass Liquefaction issued its full notice to proceed to Bechtel under the EPC Contract (Train 1 and Train 2). We designated these shares as treasury shares.

Distributions to Non-controlling Interest

During the nine months endedSeptember 30, 2013 and 2012, Cheniere Partners distributed $50.0 million and $24.6 million, respectively, to its non-affiliated common unitholders.

Operating Cash Flow

Net cash used in operations was $22.3 million and $105.0 million in the nine months endedSeptember 30, 2013 and 2012, respectively. Net cash used in operations related primarily to the general administrative overhead costs, pipeline operations costs and LNG and natural gas marketing overhead costs. The decrease in cash used in operations in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily resulted from decreased interest expense in the nine months endedSeptember 30, 2013 as a result of the capitalization of interest on Sabine Pass Liquefaction's debt, the reduction of our indebtedness outstanding in 2012 and the purchase of a royalty from Crest Energy in March 2012.

Investment in Cheniere Partners

In the nine months endedSeptember 30, 2013 and 2012, we invested $11.1 million and $534.9 million, respectively, in Cheniere Partners related to the purchase of Class B units and general partner units.

Issuance of Common Stock

 During the nine months endedSeptember 30, 2013 and 2012, we issued 18.5 million and 10.2 million shares, respectively, of restricted stock to new and existing employees.

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Results of Operations

Three Months Ended September 30, 2013 vs. Three Months Ended September 30, 2012

Our consolidated net loss attributable to common stockholders was $100.8 million, or $0.46 per share (basic and diluted), in the three months ended September 30, 2013 compared to a net loss attributable to common stockholders of $109.0 million, or $0.52 per share (basic and diluted), in the three months ended September 30, 2012. The decrease in net loss was primarily a result of decreased general and administrative expense and decreased other expense that was partially offset by increased derivative loss and increased LNG terminal operating expense. Our general and administrative expense decreased $22.3 million in the three months ended September 30, 2013 as compared to the three months ended September 30, 2012 primarily as a result of the timing of awards under bonus plans relating to Train 1, Train 2, Train 3 and Train 4 of the Liquefaction Project. Other expense decreased $12.1 million in the three months ended September 30, 2013 as compared to the three months ended September 30, 2012 primarily as result of the expenses incurred to terminate the Crest Royalty in September 2012. Derivative loss increased $22.6 million in the three months ended September 30, 2013 as compared to the three months ended September 30, 2012 primarily as a result of the change in fair value of Sabine Pass Liquefaction's interest rate derivatives to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities. LNG terminal operating expense increased $16.0 million in the three months ended September 30, 2013 as compared to the three months ended September 30, 2012 primarily as a result of the loss incurred to purchase LNG to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal and increased LNG terminal maintenance and repair costs and increased fuel costs at the Sabine Pass LNG terminal.

Nine Months Ended September 30, 2013 vs. Nine Months Ended September 30, 2012

Our consolidated net loss attributable to common stockholders was $372.7 million, or $1.71 per share (basic and diluted), in the nine months ended September 30, 2013 compared to a net loss attributable to common stockholders of $238.5 million, or $1.40 per share (basic and diluted), in the nine months ended September 30, 2012. The increase in net loss was primarily a result of increased general and administrative expense, increased loss on the early extinguishment of debt and increased LNG terminal operating expense that was partially offset by increased derivative gain, decreased interest expense, net and decreased other expense. Our general and administrative expense increased $157.7 million in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily as a result of the timing of awards under bonus plans relating to Train 1, Train 2, Train 3 and Train 4 of the Liquefaction Project. Loss on early extinguishment of debt increased $65.4 million in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily as a result of the amendment and restatement of the 2012 Liquefaction Credit Facility with the 2013 Liquefaction Credit Facilities. LNG terminal operating expense increased $39.8 million in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily as a result of the loss incurred to purchase LNG to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal and increased LNG terminal maintenance and repair costs and increased fuel costs at the Sabine Pass LNG terminal. Derivative gain increased $56.0 million in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily as a result of the change in fair value of Sabine Pass Liquefaction's interest rate derivatives to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities. Interest expense, net decreased $24.9 million in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily as a result of capitalization of interest on Sabine Pass Liquefaction's debt and the reduction of our indebtedness outstanding in 2012. Other expense decreased $12.5 million in the nine months ended September 30, 2013 as compared to the nine months ended September 30, 2012 primarily as result of the expenses incurred to terminate the Crest Royalty in September 2012.

Off-Balance Sheet Arrangements

As of September 30, 2013, 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. 

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Summary of Critical Accounting Policies and Estimates

The selection and application of accounting policies is an important process that has developed as our business activities have evolved and as the accounting rules have developed. Accounting rules generally do not involve a selection among alternatives but involve an implementation and interpretation of existing rules, and the use of judgment, to apply the accounting rules to the specific set of circumstances existing in our business. In preparing our consolidated financial statements in conformity with generally accepted accounting principles in the United States ("GAAP"), we endeavor to comply with all applicable rules on or before their adoption, and we believe that the proper implementation and consistent application of the accounting rules are critical. However, not all situations are specifically addressed in the accounting literature. In these cases, we must use our best judgment to adopt a policy for accounting for these situations. We accomplish this by analogizing to similar situations and the accounting guidance governing them. There have been no significant changes to our critical accounting policies and estimates from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2012, as amended by Amendment No. 1 on Form 10-K/A.

Recent Accounting Standards

In February 2013, the Financial Accounting Standards Board ("FASB") issued guidance that requires entities to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, entities are required to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount is required under GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under GAAP to be reclassified in their entirety to net income, entities are required to cross-reference to other disclosures required under GAAP that provide additional detail on these amounts. This standard is effective prospectively for reporting periods beginning after December 15, 2012. We adopted this standard effective January 1, 2013. The adoption of this guidance did not have an impact on our consolidated financial position, results of operations or cash flows, as it only expanded disclosures.

In December 2011 and February 2013, the FASB issued guidance that requires entities to disclose both gross and net information about both derivatives and transactions eligible for offset in the statement of financial position and instruments and transactions subject to an agreement similar to a master netting agreement. The objective of the disclosure is to facilitate comparison between those entities that prepare their financial statements on the basis of GAAP and those entities that prepare their financial statements on the basis of International Financial Reporting Standards. Retrospective presentation for all comparative periods presented is required. We adopted this guidance effective January 1, 2013. The adoption of this guidance did not have an impact on our consolidated financial position, results of operations or cash flows, as it only expanded disclosures.

There are currently no new accounting standards that have been issued that will have a significant impact on our consolidated financial position, results of operations or cash flows upon adoption.

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.

39

Marketing and Trading Commodity Price Risk

We have entered into certain instruments to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory ("LNG Inventory Derivatives") and to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate the Sabine Pass LNG terminal ("Fuel 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 LNG Inventory Derivatives and Fuel Derivatives. The VaR is calculated using the Monte Carlo simulation method. The table below provides information about our LNG Inventory Derivatives and Fuel Derivatives that are sensitive to changes in natural gas prices and interest rates as of September 30, 2013.

Hedge Description	Hedge Instrument	Contract Volume (MMBtu)	Price Range ($/MMBtu)	Final Hedge Maturity Date	Fair Value (in thousands)			VaR (in thousands)
LNG Inventory Derivatives	Fixed price natural gas swaps	1,753,376	$3.553 - $4.319	January 2014	$	186		$	26
Fuel Derivatives	Fixed price natural gas swaps	1,076,876	3.560 - 3.837	October 2014	(283		)	4

We have entered into interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities ("Interest Rate Derivatives"). In order to test the sensitivity of the fair value of the 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 Interest Rate Derivatives. This 10% change in interest rates resulted in a change in the fair value of the Interest Rate Derivatives of $30.7 million. The table below provides information about our Interest Rate Derivatives that are sensitive to changes in the forward 1-month LIBOR curve as of September 30, 2013.

Hedge Description	Initial Notional Amount (in thousands)	Maximum Notional Amount (in thousands)	Fixed Interest Rate Range (%)	Final Hedge Maturity Date	Fair Value (in thousands)		10% Change in LIBOR (in thousands)
Interest Rate Derivatives - Not Designated	$20.0 million	$3.6 billion	1.99%	May 2020	$	56,039	$	30,659

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 Securities and Exchange Commission's rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that our disclosure controls and procedures are effective.

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

PART II.    OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS

We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. In the opinion of management, as of September 30, 2013, there were no pending legal matters that could reasonably be expected to have a material adverse impact on our consolidated results of operations, financial position or cash flows. 

40

ITEM 5.    OTHER INFORMATION

Compliance Disclosure

Pursuant to Section 13(r) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), if during the quarter ended September 30, 2013, we or any of our affiliates had engaged in certain transactions with Iran or with persons or entities designated under certain executive orders, we would be required to disclose information regarding such transactions in our Quarterly Report on Form 10-Q as required under Section 219 of the Iran Threat Reduction and Syria Human Rights Act of 2012 ("ITRA"). During the quarter ended September 30, 2013, we did not engage in any transactions with Iran or with persons or entities related to Iran.

Blackstone CQP HoldCo LP, an affiliate of The Blackstone Group L.P. ("Blackstone"), is a holder of approximately 30% of the outstanding equity interests of Cheniere Partners and has three representatives on Cheniere Partners' Board of Directors. Accordingly, Blackstone may be deemed an "affiliate" of Cheniere Partners, as that term is defined in Exchange Act Rule 12b-2. We have received notice from Blackstone that it may include in its Quarterly Report on Form 10-Q for the quarter ended September 30, 2013 disclosures pursuant to ITRA regarding one of its portfolio companies that may be deemed to be an affiliate of Blackstone. Because of the broad definition of "affiliate" in Exchange Act Rule 12b-2, this portfolio company of Blackstone, through Blackstone's ownership of Cheniere Partners, may also be deemed to be an affiliate of ours.

Blackstone has reported that Travelport Limited ("Travelport") has engaged in the following activities: as part of its global business in the travel industry, Travelport provides certain passenger travel-related GDS and Airline IT Solutions services to Iran Air and Airline IT Solutions services to Iran Air Tours. The gross revenues and net profits attributable to such activities during the reporting period were reported by Travelport to be approximately $164,000 and $122,000, respectively. Blackstone has reported that Travelport intends to continue these business activities with Iran Air and Iran Air Tours as such activities are either exempt from applicable sanctions prohibitions or specifically licensed by OFAC.

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ITEM 6.    EXHIBITS

Exhibit No.	Description
10.1	Change orders 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.: (i) the Change Order CO-00026 Bundle of Changes, dated June 28, 2013, (ii) the Change Order CO-00027 16" Water Pumps, dated July 12, 2013, (iii) the Change Order CO-00028 HRU Operability, dated July 26, 2013, (iv) the Change Order CO-00029 Belleville Washers, dated August 14, 2013 and (v) the Change Order CO-0030 Soils Preparation Provisional Sum Transfer dated August 29, 2013. (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 10.1 to Cheniere Energy Partners, L.P.'s Quarterly Report on Form 10-Q (SEC File No. 001-33366), filed on November 8, 2013)
10.2	Change orders 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.: (i) the Change Order CO-0005 Credit to EPC Contract Value for TSA Work, dated June 24, 2013, (ii) the Change Order CO-0006 HRU Operability with Lean Gas & Controls Upgrade and Ultrasonic Meter Configuration and Calibration, (iii) the Change Order CO-0007 Additional Belleville Washers, dated August 15, 2013, (iv) the Change Order CO-0008 GTG Switchgear Arrangement/Upgrade Fuel Gas Heater System, dated August 26, 2013, (iv) the Change Order CO-0009 Soils Preparation Provisional Sum Transfer and Closure, dated August 26, 2013. (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 10.49 to Cheniere Energy Partners LP Holdings, LLC's Registration Statement on Form S-1 (SEC File No. 333-191298), filed on October 18, 2013)
31.1*	Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
31.2*	Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
32.1**	Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2**	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS*	XBRL Instance Document
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	XBRL Taxonomy Extension Labels Linkbase Document
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document

*	Filed herewith.
**	Furnished herewith.

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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.
By:	/s/  JERRY D. SMITH
	Jerry D. Smith Vice President and Chief Accounting Officer (on behalf of the registrant and as principal accounting officer)
Date:	November 8, 2013

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 officers 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 (the registrant's fourth fiscal quarter in the case of an annual report) 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 officers 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.

/s/ Charif Souki

Charif Souki

Chief Executive Officer

Date: November 8, 2013

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, H. Davis Thames, 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 officers 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 (the registrant's fourth fiscal quarter in the case of an annual report) 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 officers 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.

/s/ H. Davis Thames

H. Davis Thames

Chief Financial Officer

Date: November 8, 2013

EX-32.1

EXHIBIT 32.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the period ended September 30, 2013, 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 result of operations of the Company.

/s/ Charif Souki

Charif Souki

Chief Executive Officer

Date: November 8, 2013

EX-32.2

EXHIBIT 32.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the period ended September 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, H. Davis Thames, 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 result of operations of the Company.

/s/ H. Davis Thames

H. Davis Thames

Chief Financial Officer

Date: November 8, 2013

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Income Taxes

9 Months Ended

Sep. 30, 2013

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 financial statements. However, we are presently an international taxpayer and have recorded a net expense of $1.8 million and $0.1 million for international income taxes for the three months ended September 30, 2013 and 2012, respectively. We recorded a net expense of $2.8 million and $0.2 million for international income taxes for the nine months ended September 30, 2013 and 2012, respectively.

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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Share-Based Compensation (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 26.7	$ 49.8	$ 202.8	$ 54.0
Employee Service Share-based Compensation, Allocation of Recognized Period Costs, Capitalized Amount	1.3	2.2	8.6	2.2
Proceeds from Stock Options Exercised			0.3	0.8
1997 Plan and 2003 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	$ 283.7		$ 283.7
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Recognition Period			5 years 6 months
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition			3 years 4 months 25 days
Payment of 60% of total cost for EPC Contract (Train 3 and Train 4) [Member] | Long Term Commercial Milestone Bonus Award for Train 3 and Train 4 [Member] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Percentage	20.00%		20.00%
Percentage of total cost of the EPC Contract (Train 3 and Train 4)	60.00%		60.00%
Substantial completion of construction of Train 4 [Member] | Long Term Commercial Milestone Bonus Award for Train 3 and Train 4 [Member] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Percentage	20.00%		20.00%
First anniversary of substantial completion of construction of Train 4 [Member] | Long Term Commercial Milestone Bonus Award for Train 3 and Train 4 [Member] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Percentage	30.00%		30.00%
Average 120-day closing stock price is $25 [Member] | Long Term Commercial Stock Price Bonus Award for Train 3 and Train 4 [Member] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share Price	$ 25		$ 25
Average 120-day closing stock price is $25 [Member] | Long Term Commercial Stock Price Bonus Award for Train 1 and Train 2 [Domain] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Percentage	50.00%		50.00%
Average 120-day closing stock price is $35 [Member] | Long Term Commercial Stock Price Bonus Award for Train 3 and Train 4 [Member] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share Price	$ 35		$ 35
First performance milestone achieved upon closing of 2013 Sabine Pass Liquefaction Credit Facilities [Member] | Long Term Commercial Milestone Bonus Award for Train 3 and Train 4 [Member] | Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Percentage	30.00%		30.00%

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Consolidated Statements of Operations (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues
LNG terminal revenues	$ 66,735	$ 65,939	$ 199,222	$ 199,269
Marketing and trading revenues	590	(292)	441	(1,641)
Other	385	351	1,130	1,171
Total revenues	67,710	65,998	200,793	198,799
Operating costs and expenses
LNG terminal operating expense	30,098	14,056	76,425	36,606
LNG terminal development expense	11,046	11,721	50,214	54,629
Depreciation, depletion and amortization	15,246	15,233	45,533	47,001
General and administrative expense	57,096	79,427	277,971	120,236
Other	100	78	258	244
Total operating costs and expenses	113,586	120,515	450,401	258,716
Loss from operations	(45,876)	(54,517)	(249,608)	(59,917)
Other income (expense)
Interest expense, net	(52,528)	(45,504)	(134,806)	(159,719)
Loss on early extinguishment of debt	0	0	80,510	15,098
Derivative gain (loss), net	(22,335)	287	55,706	(288)
Other income (expense)	65	(12,081)	954	(11,500)
Total other expense	(74,798)	(57,298)	(158,656)	(186,605)
Loss before income taxes and non-controlling interest	(120,674)	(111,815)	(408,264)	(246,522)
Income tax provision	(1,809)	(61)	(2,751)	(211)
Net loss	(122,483)	(111,876)	(411,015)	(246,733)
Non-controlling interest	21,659	2,875	38,323	8,277
Net loss attributable to common stockholders	$ (100,824)	$ (109,001)	$ (372,692)	$ (238,456)
Net loss per share attributable to common stockholders - basic and diluted	$ (0.46)	$ (0.52)	$ (1.71)	$ (1.40)
Weighted average number of common shares outstanding - basic and diluted	220,734	208,712	217,940	170,414

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Restricted Cash and Cash Equivalents

9 Months Ended

Sep. 30, 2013

Restricted Cash and Cash Equivalents [Abstract]

Restricted Cash and Cash Equivalents

RESTRICTED CASH AND CASH EQUIVALENTS

Restricted cash and cash equivalents consist 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.

Amounts that are designated as restricted cash and cash equivalents are contractually restricted as to usage or withdrawal and will not become available to us as cash and cash equivalents. For these amounts, we have presented increases and decreases as "Investments in (uses of) of restricted cash and cash equivalents" in our Consolidated Statement of Cash Flows. These amounts that represent non-cash transactions within our Consolidated Statement of Cash Flows present the effect of sources and uses of restricted cash and cash equivalents as they relate to the changes to assets and liabilities in our Consolidated Balance Sheets. This presentation does not impact the total amount of operating, investing or financing cash flows related to these items, however , they are presented on a gross basis within each of those categories so as to reconcile the change in non-cash activity that occurs on the balance sheet from period to period.

Restricted cash and cash equivalents include the following:

Sabine Pass LNG Senior Notes Debt Service Reserve

Sabine Pass LNG, L.P. ("Sabine Pass LNG") has consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of Senior Secured Notes due 2016 (the "2016 Notes") and $420.0 million of Senior Secured Notes due 2020 (the "2020 Notes") (See Note 8—"Long-Term Debt"). Collectively, the 2016 Notes and the 2020 Notes are referred to as the "Sabine Pass LNG Senior Notes." Under the indentures governing the Sabine Pass LNG Senior Notes (the "Sabine Pass LNG Indentures"), except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied, including that 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 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 Sabine Pass LNG Indentures.

As of September 30, 2013 and December 31, 2012, we classified $53.0 million and $17.4 million, respectively, as current restricted cash and cash equivalents for the payment of interest due within twelve months. As of both September 30, 2013 and December 31, 2012, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash and cash equivalents. These cash accounts are controlled by a collateral trustee, and, therefore, are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets.

Liquefaction Reserve

In July 2012, Sabine Pass Liquefaction closed on a $3.6 billion senior secured credit facility (the "2012 Liquefaction Credit Facility"). In February and April 2013, Sabine Pass Liquefaction entered into $2.0 billion, before premium, of Senior Secured Notes due in 2021 (the "2021 Sabine Pass Liquefaction Senior Notes") and $1.0 billion of Senior Secured Notes due in 2023 (the "2023 Sabine Pass Liquefaction Senior Notes" and collectively with the 2021 Sabine Pass Liquefaction Senior Notes, the "Sabine Pass Liquefaction Senior Notes"). In May 2013, Sabine Pass Liquefaction closed four credit facilities aggregating $5.9 billion (collectively the "2013 Liquefaction Credit Facilities"), which amended and restated the 2012 Liquefaction Credit Facility. See Note 8—"Long-Term Debt". Under the terms and conditions of the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction is required to deposit all cash received into collateral accounts controlled by a collateral trustee. Therefore, all of Sabine Pass Liquefaction's cash and cash equivalents are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets. As of September 30, 2013 and December 31, 2012, we classified $133.5 million and $75.1 million, respectively, as current restricted cash and cash equivalents held by Sabine Pass Liquefaction for the payment of current liabilities related to the Liquefaction Project, and $665.1 million and $196.3 million, respectively, as non-current restricted cash and cash equivalents held by Sabine Pass Liquefaction for future Liquefaction Project construction costs.

CTPL Reserve

In May 2013, CTPL entered into a $400.0 million term loan facility (the "CTPL Credit Facility"). As of September 30, 2013, we classified $23.5 million and $87.2 million as current and non-current restricted cash and cash equivalents, respectively, held by CTPL because such funds may only be used for modifications of the Creole Trail Pipeline in order to enable bi-directional natural gas flow and for the payment of interest during construction of such modifications.

Other Restricted Cash and Cash Equivalents

As of September 30, 2013 and December 31, 2012, $339.9 million and $419.3 million, respectively, of cash and cash equivalents were held by Sabine Pass LNG and Cheniere Partners that are considered restricted to Cheniere.  As of September 30, 2013 and December 31, 2012, $28.0 million and $8.5 million, respectively, had been classified as current restricted cash and cash equivalents on our Consolidated Balance Sheets due to various other contractual restrictions. As of both September 30, 2013 and December 31, 2012, $0.5 million had been classified as non-current restricted cash and cash equivalents due to various other contractual restrictions on our Consolidated Balance Sheets.

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Accrued Liabilities (Tables)

9 Months Ended

Sep. 30, 2013

Accounts Payable and Accrued Liabilities [Abstract]

Schedule of Accrued Liabilities

As of September 30, 2013 and December 31, 2012, accrued liabilities consisted of the following (in thousands): 

	September 30,		December 31,
	2013		2012
Accrued interest expense and related fees	$	97,758	$	16,327
Payroll	25,693		6,369
LNG liquefaction costs	33,956		27,919
LNG terminal costs	1,650		977
Other accrued liabilities	12,958		7,145
Accrued liabilities	$	172,015	$	58,737

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Net Loss Per Share Attributable to Common Stockholders (Notes)

9 Months Ended

Sep. 30, 2013

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 nine months ended September 30, 2013 and 2012 (in thousands except for loss per share):

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
Weighted average common shares outstanding:
Basic	220,734			208,712			217,940			170,414
Dilutive common stock options (1)	—			—			—			—
Diluted	220,734			208,712			217,940			170,414
Basic and diluted net loss per share attributable to common stockholders	$	(0.46	)	$	(0.52	)	$	(1.71	)	$	(1.40	)

(1) Stock options and unvested stock of 18.3 million shares and 16.5 million shares representing securities that could potentially dilute basic EPS in the future were not included in the diluted net loss per share computations for the three and nine months ended September 30, 2013, respectively, because they would have been anti-dilutive. Stock options and unvested stock of 5.6 million shares and 3.1 million shares representing securities that could potentially dilute basic EPS in the future were not included in the diluted net loss per share computations for the three and nine months ended September 30, 2012, respectively, because they would have been anti-dilutive.

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Financial Instruments - Changes in Fair Value of De-Designated Interest Rate Derivatives (Details) (Not Designated as Hedging Instrument [Member], Interest Rate Contract [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ (22,481)	$ 0	$ 60,707	$ 0

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Long-Term Debt - Sabine Pass Liquefaction Credit Facilities (Details) (USD $)	3 Months Ended		9 Months Ended					1 Months Ended						9 Months Ended		1 Months Ended		1 Months Ended	4 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013 Sabine Pass Liquefaction Notes due 2023 [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member] Sabine Pass Liquefaction [Member]	Apr. 30, 2013 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Jul. 31, 2012 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Aug. 31, 2012 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 2012 Liquifaction Credit Facility - LIBOR Loans [Member] Operations [Member]	Sep. 30, 2013 2012 Liquifaction Credit Facility - LIBOR Loans [Member] Construction [Member]	Sep. 30, 2013 2021 Sabine Pass Liquefaction Notes [Member] Sabine Pass Liquefaction [Member] Rate	Sep. 30, 2013 2013 Sabine Pass Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Jul. 31, 2012 Liquefaction Credit Facility 2012 Liquefaction Credit Facility [Member]	Sep. 30, 2013 Liquefaction Credit Facility 2012 Liquefaction Credit Facility [Member]	Jul. 31, 2012 Liquefaction Credit Facility 2012 Liquifaction Credit Facility - LIBOR Loans [Member]	Sep. 30, 2013 Liquefaction Credit Facility 2013 Sabine Pass Liquefaction Credit Facility [Member]	Sep. 30, 2013 Liquefaction Credit Facility 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]	Dec. 31, 2012 Debt Service Reserve Fund [Member] Acquisition of Non-current Assets [Member] 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Operations [Member] Minimum [Member] 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]	Sep. 30, 2013 Operations [Member] Maximum [Member] 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]	Sep. 30, 2013 Construction [Member] Minimum [Member] 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]	Sep. 30, 2013 Construction [Member] Maximum [Member] 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]
Line of Credit Facility [Line Items]
Line of credit borrowing capacity									$ 3,600,000,000	$ 5,900,000,000					$ 5,900,000,000
Debt Instrument, Maturity Date									Jul. 31, 2019
Line of Credit Facility, Amount Outstanding											100,000,000				100,000,000						100,000,000
Percentage of Debt Hedged by Interest Rate Derivatives																	75.00%		75.00%
Debt Instrument, Fixed Charge, Coverage Ratio														1.25
Redemption Premium														1
Debt instrument principal amount					1,000,000,000	500,000,000	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage														5.625%
Debt Instrument, Description of Variable Rate Basis																LIBOR			LIBOR
Debt Instrument, Basis Spread on Variable Rate												3.75%	3.50%									2.30%	3.25%	2.30%	3.00%
Line of Credit Facility, Collateral Fees, Amount																178,000,000			144,000,000
Line of Credit Facility, Commitment Fee Percentage																		40.00%		40.00%
Line of Credit Facility, Amortization Period																18 years			18 years
Line of Credit Facility, Increase (Decrease) for Period, Net								1,400,000,000
Gains (Losses) on Extinguishment of Debt	$ 0	$ 0	$ (80,510,000)	$ (15,098,000)

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Business Segment Information (Tables)

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

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

	Segments
	LNG Terminal			LNG & Natural Gas Marketing				Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended September 30, 2013
Revenues (2)	$	67,558		$	16,470			$	(16,318	)	$	67,710
Intersegment revenues (losses) (3) (4)	820			15,880				(16,700		)	—
Depreciation, depletion and amortization	14,581			251				414			15,246
Non-cash compensation	3,148			4,594				20,197			27,939
Income (loss) from operations	(49,600		)	2,919				805			(45,876		)
Interest expense, net	(55,378		)	—				2,850			(52,528		)
Income (loss) before income taxes and non-controlling interest	(127,202		)	2,515				4,013			(120,674		)
Goodwill	76,819			—				—			76,819
Total assets	7,719,551			63,756				342,546			8,125,853
Expenditures for additions to long-lived assets	852,847			61				389			853,297
As of or for the Three Months Ended September 30, 2012
Revenues (2)	$	69,868		$	2,661		—	$	(6,531	)	$	65,998
Intersegment revenues (losses) (3) (4)	3,929			2,953				(6,882		)	—
Depreciation, depletion and amortization	14,566			256				411			15,233
Non-cash compensation	6,505			9,256				36,104			51,865
Loss from operations	(16,446		)	(16,462		)		(21,609		)	(54,517		)
Interest expense, net	(55,333		)	12				9,817			(45,504		)
Income (loss) before income taxes and non-controlling interest	(71,335		)	418,655				(459,135		)	(111,815		)
Goodwill	76,819			—				—			76,819
Total assets	4,136,574			42,308				204,843			4,383,725
Expenditures for additions to long-lived assets	883,798			(6		)		696			884,488
For the Nine Months Ended September 30, 2013
Revenues (2)	$	201,408		$	27,627			$	(28,242	)	$	200,793
Intersegment revenues (losses) (3) (4)	2,184			27,186				(29,370		)	—
Depreciation, depletion and amortization	43,405			751				1,377			45,533
Non-cash compensation	22,477			36,234				152,635			211,346
Loss from operations	(103,655		)	(39,543		)		(106,410		)	(249,608		)
Interest expense, net	(156,644		)	—				21,838			(134,806		)
Income (loss) before income taxes and non-controlling interest	128,441			(40,092		)		(496,613		)	(408,264		)
Expenditures for additions to long-lived assets	2,467,210			57				1,293			2,468,560
For the Nine Months Ended September 30, 2012
Revenues (2)	$	206,249		$	977			$	(8,427	)	$	198,799
Intersegment revenues (losses) (3) (4)	6,973			2,618				(9,591		)	—
Depreciation, depletion and amortization	43,810			1,815				1,376			47,001
Non-cash compensation	6,964			10,657				38,492			56,113
Income (loss) from operations	7,237			(31,788		)		(35,366		)	(59,917		)
Interest expense, net	(165,251		)	12				5,520			(159,719		)
Loss before income taxes and non-controlling interest	(158,016		)	403,369				(491,875		)	(246,522		)
Expenditures for additions to long-lived assets	931,542			1,659				1,192			934,393

(1) Includes corporate activities, oil and gas exploration, development and exploitation activities and certain intercompany eliminations. Our oil and gas exploration, development and exploitation operating 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 and international revenue allocations using a cost plus transfer pricing methodology.

(3) Intersegment revenues related to our LNG terminal business segment are primarily from tug revenues from Cheniere Marketing and the receipt of 80% of gross margins earned by Cheniere Marketing in an effort to utilize the reserved capacity at the Sabine Pass LNG terminal of Cheniere Investments under its terminal use rights assignment and agreement ("TURA") pursuant to which Cheniere Investments has the right to use Sabine Pass Liquefaction's reserved capacity at the Sabine Pass LNG terminal under Sabine Pass Liquefaction's TUA in the three and nine months ended September 30, 2013 and 2012. These LNG terminal business segment intersegment revenues are eliminated with intersegment expenses in our Consolidated Statements of Operations.

(4) Intersegment revenues (losses) related to our LNG and natural gas marketing business segment are primarily from Cheniere Marketing's tug costs and the payment of 80% of gross margins earned by Cheniere Marketing in an effort to utilize the reserved capacity at the Sabine Pass LNG terminal of Cheniere Investments under its TURA in the three and nine months ended September 30, 2013 and 2012. These LNG and natural gas marketing business segment intersegment costs are eliminated with intersegment revenues in our Consolidated Statements of Operations.

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Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2013

Financial Instruments [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of September 30, 2013 and December 31, 2012, which are classified as other current assets, other current liabilities and other non-current liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	September 30, 2013										December 31, 2012
	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
LNG Inventory Derivatives asset	$	—	$	186		$	—	$	186		$	—	$	237		$	—	$	237
Fuel Derivatives (liability)	—		(283		)	—		(283		)	—		(98		)	—		(98		)
Interest Rate Derivatives asset (liability)	—		56,039			—		56,039			—		(26,424		)	—		(26,424		)

Fair Value, by Balance Sheet Grouping

:

		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2013			December 31, 2012
LNG Inventory Derivatives asset	Prepaid expenses and other	$	186		$	237
Fuel Derivatives (liability)	Prepaid expenses and other	(283		)	(98		)

Other Financial Instruments (in thousands):

	September 30, 2013				December 31, 2012
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 Notes, net of discount (1)	$	1,650,634	$	1,811,570	$	1,647,113	$	1,824,177
2020 Notes (1)	420,000		425,250		420,000		437,850
2021 Sabine Pass Liquefaction Senior Notes (1)	2,011,897		1,951,540		—		—
2023 Sabine Pass Liquefaction Senior Notes (1)	1,000,000		952,500		—		—
2012 Liquefaction Credit Facility (2)	—		—		100,000		100,000
2013 Liquefaction Credit Facilities (2)	100,000		100,000		—		—
CTPL Credit Facility (3)	391,665		400,000		—		—

(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 September 30, 2013 and December 31, 2012, as applicable.

(2) The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and Sabine Pass Liquefaction has the ability to call this debt at anytime without penalty.

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location

three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013			2012		2013		2012
Interest Rate Derivatives - Not Designated gain (loss)	$	(22,481	)	$	—	$	60,707	$	—

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in marketing and trading revenues (losses) on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
LNG Inventory Derivatives gain (loss)	$	14		$	(265	)	$	(394	)	$	599
Fuel Derivatives loss	(57		)	—			(57		)	—

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013			2012		2013			2012
LNG Inventory Derivatives gain	$	201		$	—	$	976		$	—
Fuel Derivatives gain (loss)	(55		)	287		(3		)	(288		)

Schedule of Derivative Instruments [Table Text Block]

commodity 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 Sheet			Net Amounts Presented in the Consolidated Balance Sheet			Gross Amounts Not Offset in the Consolidated Balance Sheet
Offsetting Derivative Assets (Liabilities)										Derivative Instrument		Cash Collateral Received (Paid)		Net Amount
As of September 30, 2013:
Fuel Derivatives	$	(283	)	$	(283	)	$	—		$	—	$	—	$	—
LNG Inventory Derivatives	186						186			—		—		186
Interest Rate Derivatives - Not Designated	64,309			—			64,309			—		—		64,309
Interest Rate Derivatives - Not Designated	(8,270		)	—			(8,270		)	—		—		(8,270		)
As of December 31, 2012:
Fuel Derivatives	(98		)	(98		)	—			—		—		—
LNG Inventory Derivatives	237			—			237			—		—		237
Interest Rate Derivatives - Designated	(21,290		)	—			(21,290		)	—		—		(21,290		)
Interest Rate Derivatives - Not Designated	(5,134		)	—			(5,134		)	—		—		(5,134		)

Schedule of Notional Amounts of Outstanding Derivative Positions

	Initial Notional Amount	Maximum Notional Amount	Effective Date	Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
Interest Rate Derivatives - Not Designated	$20.0 million	$2.9 billion	August 14, 2012	July 31, 2019	1.98%	One-month LIBOR
Interest Rate Derivatives - Not Designated	—	$671.0 million	June 5, 2013	May 28, 2020	2.05%	One-month LIBOR

Schedule of Interest Rate Derivatives

:

		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2013		December 31, 2012
Interest Rate Derivatives - Not Designated	Non-current derivative assets	$	64,309	$	—
Interest Rate Derivatives - Designated	Non-current derivative liabilities	—		21,290
Interest Rate Derivatives - Not Designated	Other current liabilities	8,270		—
Interest Rate Derivatives - Not Designated	Non-current derivative liabilities	—		5,134

Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)

The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the nine months endedSeptember 30, 2013 and 2012:

	Gain (Loss) in Other Comprehensive Income						Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	2013			2012			2013		2012		2013			2012
Interest Rate Derivatives - Designated	$	21,297		$	(29,676	)	$	—	$	—	$	(5,806	)	$	—
Interest Rate Derivatives - Settlements	(30		)	—			—		—		(167		)	—

The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the three months ended September 30, 2013 and 2012:

	Gain (Loss) in Other Comprehensive Income					Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	2013		2012			2013		2012		2013		2012
Interest Rate Derivatives - Designated	$	—	$	(29,676	)	$	—	$	—	$	—	$	—

Schedule of Financial Instruments

commodity 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 Sheet			Net Amounts Presented in the Consolidated Balance Sheet			Gross Amounts Not Offset in the Consolidated Balance Sheet
Offsetting Derivative Assets (Liabilities)										Derivative Instrument		Cash Collateral Received (Paid)		Net Amount
As of September 30, 2013:
Fuel Derivatives	$	(283	)	$	(283	)	$	—		$	—	$	—	$	—
LNG Inventory Derivatives	186						186			—		—		186
Interest Rate Derivatives - Not Designated	64,309			—			64,309			—		—		64,309
Interest Rate Derivatives - Not Designated	(8,270		)	—			(8,270		)	—		—		(8,270		)
As of December 31, 2012:
Fuel Derivatives	(98		)	(98		)	—			—		—		—
LNG Inventory Derivatives	237			—			237			—		—		237
Interest Rate Derivatives - Designated	(21,290		)	—			(21,290		)	—		—		(21,290		)
Interest Rate Derivatives - Not Designated	(5,134		)	—			(5,134		)	—		—		(5,134		)

XML

Financial Instruments - Fair Value of Interest Rate Derivatives by Balance Sheet Location (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities, at Fair Value	$ 0	$ 21,290
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Non-current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities, at Fair Value	0	5,134
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Noncurrent Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Assets, at Fair Value	64,309	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Derivative Liabilities, at Fair Value	$ 8,270	$ 0
2012 Liquefaction Credit Facility [Member] | Liquefaction Credit Facility
Derivatives, Fair Value [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives	75.00%

XML

Variable Interest Entity (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	1 Months Ended		1 Months Ended			3 Months Ended	12 Months Ended		1 Months Ended	8 Months Ended					1 Months Ended	3 Months Ended	8 Months Ended
	Apr. 30, 2007 Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 Cheniere Energy Partners, LP [Member]	Sep. 30, 2011 common units [Member]	Sep. 30, 2012 common units [Member] Cheniere Energy Partners, LP [Member]	Sep. 30, 2011 common units [Member] Cheniere Energy Partners, LP [Member]	Mar. 31, 2013 common units [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 common units [Member] Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 common units [Member] Sabine Pass LNG terminal [Member] Cheniere Energy Partners, LP [Member]	May 31, 2012 Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 Class B Unit [Member] Sabine Pass LNG terminal [Member] Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 Subordinated Units [Member] Sabine Pass LNG terminal [Member] Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 General Partner [Member] Sabine Pass LNG terminal [Member]	Sep. 30, 2013 Minimum [Member] Cheniere Energy Partners, LP [Member]	Aug. 31, 2012 Blackstone CQP Holdco LP [Member] Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 Blackstone CQP Holdco LP [Member] Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 Blackstone CQP Holdco LP [Member] Class B Unit [Member] Cheniere Energy Partners, LP [Member]
Variable Interest Entity [Line Items]
Partners' Capital Account, Units, Sold in Public Offering	15.5				3.0		8.0
Ownership Interest		57.90%											0.00%	0.00%
Common units held								12.0			45.3	135.4		50.0
Price per Common Unit			$ 15.25	$ 25.07					$ 15.00
Common units sold in private placement						17.6				100.0					33.3	66.7	100.0

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Long-Term Debt - 2012 Liquefaction Credit Facility (Details) (USD $)	3 Months Ended		9 Months Ended		1 Months Ended							1 Months Ended		1 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Apr. 30, 2013 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Jul. 31, 2012 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Aug. 31, 2012 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Sabine Pass Liquefaction Notes due 2023 [Member] Sabine Pass Liquefaction [Member]	Jul. 31, 2012 Liquefaction Credit Facility 2012 Liquefaction Credit Facility [Member]	Sep. 30, 2013 Liquefaction Credit Facility 2012 Liquefaction Credit Facility [Member]	Jul. 31, 2012 Liquefaction Credit Facility 2012 Liquifaction Credit Facility - LIBOR Loans [Member]	Sep. 30, 2013 Construction [Member] 2012 Liquifaction Credit Facility - LIBOR Loans [Member]	Sep. 30, 2013 Operations [Member] 2012 Liquifaction Credit Facility - LIBOR Loans [Member]	Dec. 31, 2012 Debt Service Reserve Fund [Member] Acquisition of Non-current Assets [Member] 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]
Line of Credit Facility [Line Items]
Line of credit borrowing capacity						$ 3,600,000,000	$ 5,900,000,000
Debt Instrument, Maturity Date						Jul. 31, 2019
Line of Credit Facility, Amount Outstanding								100,000,000									100,000,000
Debt Instrument, Description of Variable Rate Basis												LIBOR
Line of Credit Facility, Amortization Period												18 years
Debt Instrument, Basis Spread on Variable Rate															3.50%	3.75%
Line of Credit Facility, Collateral Fees, Amount												178,000,000
Line of Credit Facility, Commitment Fee Percentage														40.00%
Percentage of Debt Hedged by Interest Rate Derivatives													75.00%
Debt instrument principal amount									500,000,000	2,000,000,000	1,000,000,000
Line of Credit Facility, Increase (Decrease) for Period, Net					1,400,000,000
Gains (Losses) on Extinguishment of Debt	$ 0	$ 0	$ (80,510,000)	$ (15,098,000)

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Financial Instruments - Derivatives Gross Presentation on Condsolidated Balance Sheet (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivative [Line Items]
Derivative, Collateral, Right to Reclaim Cash	$ 6,100	$ 5,900
Fuel Derivatives [Member]
Derivative [Line Items]
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative Liability, Fair Value, Amount Offset Against Collateral	(283)	(98)
Derivative Liability, Fair Value, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Gross Liability	(283)	(98)
LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	186	237
Derivative Asset, Fair Value, Amount Offset Against Collateral		0
Derivative Asset, Fair Value, Net	186	237
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Net		(26,424)
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net		0
Derivative Liability, Fair Value, Amount Offset Against Collateral		0
Derivative Liability, Fair Value, Net		(21,290)
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability, Fair Value, Gross Liability		(21,290)
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	64,309
Derivative Asset, Fair Value, Amount Offset Against Collateral	0
Derivative Asset, Fair Value, Net	64,309
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	0	0
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	0
Derivative Liability, Fair Value, Net	(8,270)	(5,134)
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Gross Liability	(8,270)	(5,134)
Not Designated as Hedging Instrument [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Net	$ 56,039

XML

Property, Plant and Equipment Schedule of Property, Plant and Equipment (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 5,705,567,000		$ 5,705,567,000		$ 3,282,305,000
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Depreciation	14,400,000	14,500,000	43,000,000	43,000,000
Interest Costs Capitalized	30,200,000	14,000,000	125,000,000
Accumulated depreciation, depletion and amortization	278,071,000		278,071,000		235,275,000
Property, plant and equipment, net	5,697,319,000		5,697,319,000		3,273,516,000
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,233,748,000		2,233,748,000		2,233,595,000
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	3,735,876,000		3,735,876,000		1,269,798,000
LNG site and related costs, net [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	5,766,000		5,766,000		5,398,000
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Depreciation	800,000	800,000	2,500,000	3,600,000
Accumulated depreciation, depletion and amortization	31,630,000		31,630,000		29,127,000
Property, plant and equipment, net	8,248,000		8,248,000		8,789,000
Computer and office equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	7,808,000		7,808,000		7,014,000
Furniture and Fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	4,167,000		4,167,000		4,057,000
Computer Software [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,125,000		13,125,000		13,012,000
Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	7,226,000		7,226,000		6,989,000
Other Fixed Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 7,552,000		$ 7,552,000		$ 6,844,000

XML

Financial Instruments - Fair Value of Financial Instruments by Balance Sheet Location (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended		3 Months Ended					3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013 LNG Inventory Derivatives [Member]	Sep. 30, 2013 LNG Inventory Derivatives [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 LNG Inventory Derivatives [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 LNG Inventory Derivatives [Member] Other Current Liabilities [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 LNG Inventory Derivatives [Member] Prepaid Expenses And Other [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Fuel Derivatives [Member]	Sep. 30, 2012 Fuel Derivatives [Member]	Sep. 30, 2013 Fuel Derivatives [Member]	Sep. 30, 2012 Fuel Derivatives [Member]	Sep. 30, 2013 Fuel Derivatives [Member] Fair Value, Inputs, Level 2 [Member]	Dec. 31, 2012 Fuel Derivatives [Member] Fair Value, Inputs, Level 2 [Member]	Dec. 31, 2012 Fuel Derivatives [Member] Other Current Liabilities [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Fuel Derivatives [Member] Prepaid Expenses And Other [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative gain (loss)	$ (22,335)	$ 287	$ 55,706	$ (288)	$ 14					$ (55)	$ 287	$ (3)	$ (288)
Derivative Assets, Current						186	237	186	237
Derivative Liabilities, Current														$ (283)	$ (98)	$ (98)	$ (283)

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Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2013

Debt Disclosure [Abstract]

Schedule of Debt

As of September 30, 2013 and December 31, 2012, our long-term debt consisted of the following (in thousands): 

	September 30,			December 31,
	2013			2012
Long-term debt
2016 Notes	$	1,665,500		$	1,665,500
2020 Notes	420,000			420,000
2021 Sabine Pass Liquefaction Senior Notes	2,000,000			—
2023 Sabine Pass Liquefaction Senior Notes	1,000,000			—
2012 Liquefaction Credit Facility	—			100,000
2013 Liquefaction Credit Facilities	100,000			—
CTPL Credit Facility	400,000			—
Total long-term debt	5,585,500			2,185,500
Long-term debt premium (discount)
2016 Notes	(14,866		)	(18,387		)
2021 Sabine Pass Liquefaction Senior Notes	11,897			—
CTPL Credit Facility	(8,336		)	—
Total long-term debt, net	$	5,574,195		$	2,167,113

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Consolidated Statements of Stockholders Equity (Deficit) (USD $) In Thousands, unless otherwise specified	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Accumulated Deficit	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Common Stock	Common Stock Accumulated Other Comprehensive Loss	Common Stock Noncontrolling Interest
Stockholders' Equity, Beginning of Period at Dec. 31, 2012	$ 2,261,605	$ 671	$ (39,115)	$ 2,168,781	$ (1,592,985)	$ (27,351)	$ 1,751,604
Shares Issued, Beginning of Period at Dec. 31, 2012		223,397	4,727
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances of stock		23
Issuances of stock	274	0		274
Issuances of restricted stock		18,531
Issuances of restricted stock	0	56		(56)
Forfeitures of restricted stock		(129)	70
Forfeitures of restricted stock	0	0	0
Stock-based compensation	211,346			211,346
Shares Paid for Tax Withholding for Share Based Compensation		(3,013)	3,013
Adjustments Related to Tax Withholding for Share-based Compensation	(89,137)	9	89,137	(9)
Tax benefit from stock-based compensation	2,070
Foreign currency translation	111					111
Interest rate cash flow hedges	27,239					25,207	2,032
Loss attributable to non-controlling interest	(38,323)						(38,323)
Sale of common units to non-controlling interest								363,902	2,033	361,869
Distribution to non-controlling interest	(50,046)						(50,046)
Net loss	(372,692)				(372,692)
Stockholders' Equity, End of Period at Sep. 30, 2013	$ 2,316,349	$ 718	$ (128,252)	$ 2,382,424	$ (1,965,677)	$ 0	$ 2,027,136
Shares Issued, End of Period at Sep. 30, 2013		238,809	7,810

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ORGANIZATION AND NATURE OF OPERATIONS (Notes)

9 Months Ended

Sep. 30, 2013

ORGANIZATION AND NATURE OF OPERATIONS [Abstract]

Nature of Operations [Text Block]

ORGANIZATION AND NATURE OF OPERATIONS

Cheniere Energy, Inc., a Delaware corporation, is a Houston-based energy company primarily engaged in liquefied natural gas ("LNG") related businesses. We own and operate the Sabine Pass liquefied natural gas ("LNG") terminal in Louisiana through our 57.9% ownership interest in and management agreements with Cheniere Energy Partners, L.P. ("Cheniere Partners") (NYSE MKT: CQP), which is a publicly traded partnership that we created in 2007.  The Sabine Pass LNG terminal is located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast. The Sabine Pass LNG terminal has regasification facilities owned by Cheniere Partners' wholly owned subsidiary, Sabine Pass LNG, L.P. ("Sabine Pass LNG") that includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with capacity of up to 265,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d.

Cheniere Partners is developing natural gas liquefaction facilities (the "Liquefaction Project") at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, Sabine Pass Liquefaction, LLC ("Sabine Pass Liquefaction"). We plan to construct up to six Trains, which are in various stages of development. Each Train is expected to have nominal production capacity of approximately 4.5 million tonnes per annum ("mtpa") of LNG.

In May 2013, we sold our ownership interests in Cheniere Creole Trail Pipeline, L.P. ("CTPL") and Cheniere Pipeline GP Interests, LLC (collectively, the "Creole Trail Pipeline Business") to Cheniere Partners for $480.0 million and were reimbursed $13.9 million for certain expenditures incurred prior to the closing date.  Concurrent with the Creole Trail Pipeline Business sale closing, we acquired 12.0 million Class B units from Cheniere Partners for aggregate consideration of $180.0 million pursuant to a unit purchase agreement between Cheniere Partners and Cheniere Class B Units Holdings, LLC, our wholly owned subsidiary.  As a result of the two transactions, we received net cash of $313.9 million.

Approximately one-half of the receiving capacity at the Sabine Pass LNG terminal is contracted to two multinational energy companies. The other half is held by Sabine Pass Liquefaction for use in connection with the Liquefaction Project. One of our wholly owned subsidiaries, Cheniere Marketing, LLC ("Cheniere Marketing"), markets LNG on its own behalf, and through a series of agreements, has the right to utilize the regasification capacity held by Sabine Pass Liquefaction during the construction phase of the Liquefaction Project. Cheniere Marketing also holds a 104.0 million MMBtu per year LNG sale and purchase agreement ("SPA") with Sabine Pass Liquefaction under which it has the right to purchase LNG from Sabine Pass Liquefaction for a tiered incentive-based fee.

We are also in various stages of developing other projects, including LNG facilities and associated pipelines, each of which, among other things, will require acceptable commercial and financing arrangements before we make a final investment decision.

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

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Property, Plant and Equipment

9 Months Ended

Sep. 30, 2013

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

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

	September 30,			December 31,
	2013			2012
LNG terminal costs
LNG terminal	$	2,233,748		$	2,233,595
LNG terminal construction-in-process	3,735,876			1,269,798
LNG site and related costs, net	5,766			5,398
Accumulated depreciation	(278,071		)	(235,275		)
Total LNG terminal costs, net	5,697,319			3,273,516
Fixed assets and other
Computer and office equipment	7,808			7,014
Furniture and fixtures	4,167			4,057
Computer software	13,125			13,012
Leasehold improvements	7,226			6,989
Other	7,552			6,844
Accumulated depreciation	(31,630		)	(29,127		)
Total fixed assets, net	8,248			8,789
Property, plant and equipment, net	$	5,705,567		$	3,282,305

LNG Terminal Costs

Depreciation expense related to the Sabine Pass LNG terminal totaled $14.4 million and $14.5 million for the three months ended September 30, 2013 and 2012, respectively. Depreciation expense related to the Sabine Pass LNG terminal totaled $43.0 million for each of the nine months endedSeptember 30, 2013 and 2012.

In June 2012, we began capitalizing costs associated with Train 1 and Train 2 of the Liquefaction Project, and in May 2013, we began capitalizing costs associated with Train 3 and Train 4 of the Liquefaction Project. For the three months ended September 30, 2013 and 2012, we capitalized $30.2 million and $14.0 million of interest expense related to the construction of the Liquefaction Project, respectively. For the nine months endedSeptember 30, 2013 and 2012, we capitalized $125.0 million and $14.0 million of interest expense related to the construction of the Liquefaction Project, respectively.

Fixed Assets and Other

Depreciation expense related to our fixed assets and other totaled $0.8 million for each of the three months ended September 30, 2013 and 2012. Depreciation expense related to our fixed assets and other totaled $2.5 million and $3.6 million for the nine months endedSeptember 30, 2013 and 2012, respectively.

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Basis of Presentation (Notes)

9 Months Ended

Sep. 30, 2013

Basis of Presentation [Abstract]

Basis of Accounting, Policy [Policy Text Block]

BASIS OF PRESENTATION

The accompanying unaudited Consolidated Financial Statements of Cheniere Energy, Inc. have been prepared in accordance with generally accepted accounting principles in the United States ("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.

Results of operations for the three and nine months ended September 30, 2013 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2013.

Certain reclassifications have been made to prior period information to conform to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows. 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, 2012, as amended by Amendment No. 1 on Form 10-K/A.

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Long-Term Debt - CTPL Credit Facility (Details) (USD $)			9 Months Ended
	Sep. 30, 2013 Creole Trail Pipeline Credit Facility [Member]	Dec. 31, 2012 Creole Trail Pipeline Credit Facility [Member]	Sep. 30, 2013 Creole Trail Pipeline Credit Facility - LIBOR Loans [Member]	Sep. 30, 2013 Cheniere Creole Trail Pipeline LP [Member] Creole Trail Pipeline Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt instrument principal amount				$ 400,000,000
Debt Instrument, Unamortized Discount	$ (8,336,000)	$ 0		$ 10,000,000
Debt Instrument, Description of Variable Rate Basis			LIBOR
Debt Instrument, Basis Spread on Variable Rate			3.25%

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Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2013

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

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

	Nine Months Ended September 30,
	2013		2012
Cash paid during the year for interest, net of amounts capitalized and deferred	$	56,428	$	117,190
LNG terminal costs funded with accounts payable and accrued liabilities	80,557		52,830

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Property, Plant and Equipment (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Depreciation	$ 14.4	$ 14.5	$ 43.0	$ 43.0
Interest Costs Capitalized	30.2	14.0	125.0
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Depreciation	$ 0.8	$ 0.8	$ 2.5	$ 3.6

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Long-Term Debt - Sabine Pass LNG Senior Notes (Details) (USD $)	9 Months Ended					3 Months Ended		9 Months Ended
	Sep. 30, 2012 Senior Notes	Sep. 30, 2013 Sabine Pass LNG, LP [Member] 2016 Senior Notes [Member]	Dec. 31, 2012 Sabine Pass LNG, LP [Member] 2016 Senior Notes [Member]	Sep. 30, 2013 Sabine Pass LNG, LP [Member] 2020 Notes	Dec. 31, 2012 Sabine Pass LNG, LP [Member] 2020 Notes	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes	Sep. 30, 2012 Sabine Pass LNG, LP [Member] Senior Notes	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes Rate	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes 2020 Notes	Dec. 31, 2012 Sabine Pass LNG, LP [Member] Senior Notes 2020 Notes
Debt Instrument [Line Items]
Debt instrument principal amount		$ 1,665,500,000	$ 166,500,000						$ 420,000,000	$ 420,000,000
Debt Instrument, Interest Rate, Stated Percentage		7.50%	7.50%	6.50%	6.50%
Debt instrument fixed charge coverage ratio								2
Distribution Made to Member or Limited Partner, Cash Distributions Paid	182,900,000					93,000,000	36,200,000	242,100,000
Redemption of Debt Instrument, Percentage									35.00%
Redemption Premium									$ 1.065
Percentage if 2020 Notes Outstanding									65.00%

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Supplemental Cash Flow Information (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Supplemental Cash Flow Information [Abstract]
Cash paid during the year for interest, net of amounts capitalized	$ 56,428	$ 117,190
LNG terminal costs funded with accounts payable and accrued liabilities	$ 80,557	$ 52,830

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Financial Instruments - Fair Value of Other Financial Instruments (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Carrying (Reported) Amount, Fair Value Disclosure [Member] | 2016 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	$ 1,650,634	[1]	$ 1,647,113	[1]
Carrying (Reported) Amount, Fair Value Disclosure [Member] | 2020 Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	420,000	[1]	420,000	[1]
Carrying (Reported) Amount, Fair Value Disclosure [Member] | 2021 Sabine Pass Liquefaction Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	2,011,897	[1]	0	[1]
Carrying (Reported) Amount, Fair Value Disclosure [Member] | Sabine Pass Liquefaction Notes due 2023 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	1,000,000	[1]	0	[1]
Carrying (Reported) Amount, Fair Value Disclosure [Member] | 2012 Liquefaction Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	0	[2]	100,000	[2]
Carrying (Reported) Amount, Fair Value Disclosure [Member] | 2013 Sabine Pass Liquefaction Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	100,000	[2]	0	[2]
Carrying (Reported) Amount, Fair Value Disclosure [Member] | Creole Trail Pipeline Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	391,665	[3]	0	[3]
Estimate of Fair Value, Fair Value Disclosure [Member] | 2016 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,811,570	[1]	1,824,177	[1]
Estimate of Fair Value, Fair Value Disclosure [Member] | 2020 Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	425,250	[1]	437,850	[1]
Estimate of Fair Value, Fair Value Disclosure [Member] | 2021 Sabine Pass Liquefaction Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	1,951,540	[1]	0	[1]
Estimate of Fair Value, Fair Value Disclosure [Member] | Sabine Pass Liquefaction Notes due 2023 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	952,500		0	[1]
Estimate of Fair Value, Fair Value Disclosure [Member] | 2012 Liquefaction Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	0	[2]	100,000	[2]
Estimate of Fair Value, Fair Value Disclosure [Member] | 2013 Sabine Pass Liquefaction Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	100,000	[2]	0	[2]
Estimate of Fair Value, Fair Value Disclosure [Member] | Creole Trail Pipeline Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	$ 400,000	[3]	$ 0	[3]

[1] The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2013 and December 31, 2012, as applicable.

[2] The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and Sabine Pass Liquefaction has the ability to call this debt at anytime without penalty.

[3] The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and CTPL has the ability to call this debt at anytime without penalty.

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Financial Instruments - Notional Amounts of Derivative Instruments (Details) (Sabine Pass Liquefaction [Member], Interest Rate Contract [Member], Not Designated as Hedging Instrument [Member], USD $) In Billions, unless otherwise specified	Sep. 30, 2013
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 0
Derivative, Average Fixed Interest Rate	1.98%
Maximum [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 0
Effective Date June 5, 2013 [Domain]
Derivative [Line Items]
Derivative, Average Fixed Interest Rate	2.05%

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Consolidated Balance Sheet Parentheticals (USD $)	Sep. 30, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]
Preferred Stock, Par Value (US$ per share)	$ 0.0001	$ 0.0001
Preferred Stock, Shares Authorized	5,000,000.0	5,000,000.0
Preferred Stock, Shares Issued	0	0
Common Stock, Par Value Per Share (US$ per share)	$ 0.003	$ 0.003
Common Stock, Shares Authorized	480,000,000	480,000,000.0
Common Stock, Shares, Issued	238,800,000.0	223,400,000.0
Common Stock, Shares, Outstanding	238,800,000.0	223,400,000.0
Treasury Stock, Shares	7,800,000.0	4,700,000.0

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Accrued Liabilities

9 Months Ended

Sep. 30, 2013

Accounts Payable and Accrued Liabilities [Abstract]

Accrued Liabilities

ACCRUED LIABILITIES

As of September 30, 2013 and December 31, 2012, accrued liabilities consisted of the following (in thousands): 

	September 30,		December 31,
	2013		2012
Accrued interest expense and related fees	$	97,758	$	16,327
Payroll	25,693		6,369
LNG liquefaction costs	33,956		27,919
LNG terminal costs	1,650		977
Other accrued liabilities	12,958		7,145
Accrued liabilities	$	172,015	$	58,737

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Consolidated Statements of Comprehensive Loss (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Statement of Other Comprehensive Income [Abstract]
Net loss	$ (122,483)	$ (111,876)	$ (411,015)	$ (246,733)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Loss on settlements retained in other comprehensive income	0	0	(30)	0
Change in fair value of of interest rate cash flow hedges	0	(29,676)	21,297	(29,676)
Losses reclassified into earnings as a result of discontinuance of cash flow hedge accounting	0	0	5,973	0
Foreign currency translation	135	153	111	137
Total other comprehensive income (loss)	135	(29,523)	27,351	(29,539)
Comprehensive loss	(122,348)	(141,399)	(383,664)	(276,272)
Comprehensive loss attributable to noncontrollin interest	21,659	2,875	36,291	8,277
Comprehensive loss attributable to common stockholders	$ (100,689)	$ (138,524)	$ (347,373)	$ (267,995)

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012
Current assets
Cash and cash equivalents	$ 374,164	$ 201,711	$ 214,995
Restricted cash and cash equivalents	577,945	520,263
Accounts and interest receivable	26,079	3,486
LNG inventory	14,401	7,045
Prepaid expenses and other	16,471	16,058
Total current assets	1,009,060	748,563
Non-current restricted cash and cash equivalents	828,858	272,924
Property, plant and equipment, net	5,705,567	3,282,305
Debt issuance costs, net	340,856	220,949
Non-current derivative assets	64,309	0
Goodwill	76,819	76,819
Intangible LNG assets	4,366	4,356
Advances under long-term contracts	12,528		0
Other	83,490	33,169
Total assets	8,125,853	4,639,085
Current liabilities
Accounts payable	6,345	74,360
Accrued liabilities	172,015	58,737
Deferred revenue	26,585	26,540
Other	8,292	126
Total current liabilities	213,237	159,763
Long-term debt, net of discount	5,574,195	2,167,113
Non-current derivative liabilities	0	26,424
Long-term deferred revenue	18,500	21,500
Other non-current liabilities	3,572	2,680
Commitments and contingencies
Stockholders' deficit
Preferred stock, $.0001 par value, 5.0 million shares authorized, none issued	0	0
Common stock, $.003 par value, Authorized: 480.0 million shares at September 30, 2013 and December 31, 2012; Issued and outstanding: 238.9 million shares and 223.4 million shares at September 30, 2013 and December 31, 2012, respectively	718	671
Treasury stock: 7.8 million shares and 4.7 million shares at September 30, 2013 and December 31, 2012, respectively	(128,252)	(39,115)
Additional paid-in-capital	2,382,424	2,168,781
Accumulated deficit	(1,965,677)	(1,592,985)
Accumulated other comprehensive loss	0	(27,351)
Total stockholders' equity	289,213	510,001
Non-controlling interest	2,027,136	1,751,604
Total equity	2,316,349	2,261,605
Total liabilities and equity	$ 8,125,853	$ 4,639,085

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Income Taxes - Provision for Income Taxes (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Income Tax Disclosure [Abstract]
Income tax benefit (provision)	$ (1,809)	$ (61)	$ (2,751)	$ (211)

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ORGANIZATION AND NATURE OF OPERATIONS Organization and Nature of Operations (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended					9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013 Sabine Pass LNG, LP [Member] m3	Sep. 30, 2013 Sabine Pass Liquefaction [Member] trains	May 28, 2013 Creole Trail Pipeline Business [Domain]	Sep. 30, 2013 Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 Class B Unit [Member]	Sep. 30, 2013 LNG Sale and Purchase Agreement [Member] Cheniere Marketing, LLC [Member] Sabine Pass Liquefaction [Member] MMBTU
Organization and nature of operations [Line Items]
Business Acquisition, Cost of Acquired Entity, Cash Paid	$ 313.9
Purchase Commitment, Excess And Uncommitted LNG Produced							104,000,000
Ownership Interest					57.90%
Storage Capacity		16.9
Volume of vessel		265,000
Regasification capacity		4.0
Number of Liquefaction LNG Trains			6
Train nominal capacity	4,500,000.0
Business Acquisition, Cost of Acquired Entity, Purchase Price				480.0
Reimbursement of costs incurred prior to acquisition closing date				13.9
Partners' Capital Account, Sale of Units						12.0
Proceeds From Sale Of Class B Units	$ 180.0

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Non-Controlling Interest (Tables)

9 Months Ended

Sep. 30, 2013

Noncontrolling Interest [Abstract]

Schedule of Noncontrolling Interest

The following table sets forth the components of our non-controlling interest balance since inception attributable to third-party investors’ interests at September 30, 2013 (in thousands): 

Net proceeds from Cheniere Partners’ issuance of common units (1)	$	719,572
Net proceeds from CLNGH’s sale of Cheniere Partners common units (2)	203,946
Distributions to Cheniere Partners’ non-controlling interest	(207,396		)
Net proceeds from Cheniere Partners' issuance of Class B units (3)	1,387,339
Non-controlling interest share of loss of Cheniere Partners	(76,325		)
Non-controlling interest at September 30, 2013	$	2,027,136

(1) In March and April 2007, we and Cheniere Partners completed a public offering of 15.5 million Cheniere Partners common units (the "Cheniere Partners IPO"). Cheniere Partners received $98.4 million in net proceeds from the issuance of its common units to the public.

In January 2011, Cheniere Partners initiated an at-the-market program to sell up to 1.0 million common units, the proceeds from which would be used primarily to fund development costs associated with the Liquefaction Project. As of December 31, 2011, Cheniere Partners had sold 0.5 million common units with net proceeds of $9.0 million. During the year endedDecember 31, 2012, Cheniere Partners sold 0.5 million common units with net proceeds of $11.1 million.

In September 2011, Cheniere Partners sold 3.0 million common units in an underwritten public offering and 1.1 million common units to Cheniere Common Units Holding, LLC, a wholly owned subsidiary of Cheniere, at a price of $15.25 per common unit. Cheniere Partners received net proceeds of $43.3 million and $16.4 million from the public offering and Cheniere Common Units Holding, LLC sale, respectively.

In September 2012, Cheniere Partners sold 8.0 million common units in an underwritten public offering at a price of $25.07 per common unit for net cash proceeds of $194.0 million.

In March 2013, Cheniere Partners sold 17.6 million common units in a registered direct offering to institutional investors at a price of $20.75 per common unit for net proceeds of $364.8 million.

(2) In conjunction with the Cheniere Partners IPO, Cheniere LNG Holdings, LLC ("CLNGH") sold a portion of the Cheniere Partners common units held by it to the public, realizing net proceeds of $203.9 million, which included $39.4 million of net proceeds realized once the underwriters exercised their option to purchase an additional 2.0 million common units from Holdings.

(3) In May 2012, Cheniere Partners, Cheniere and Blackstone CQP Holdco LP ("Blackstone") entered into a unit purchase agreement (the "Blackstone Unit Purchase Agreement") whereby Cheniere Partners agreed to sell to Blackstone in a private placement 100.0 million Class B units of Cheniere Partners ("Class B units") at a price of $15.00 per Class B unit. Cheniere Partners had issued and sold all 100.0 million Class B units to Blackstone as of December 31, 2012. See Note 5—"Variable Interest Entity".

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Financial Instruments - Fair Value and Settlements of Derivatives (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Derivative [Line Items]
Derivative, Collateral, Right to Reclaim Cash	$ 6,100,000		$ 6,100,000		$ 5,900,000
Derivative gain (loss)	(22,335,000)	287,000	55,706,000	(288,000)
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	0	0	(30,000)	0
Interest Rate Contract [Member]
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net			0	0
Derivative gain (loss) recognized in income (ineffective portion and amount excluded from Effectiveness Testing)			(167,000)	0
Fuel Derivatives [Member]
Derivative [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0		0		0
Derivative gain (loss)	(55,000)	287,000	(3,000)	(288,000)
LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0		0		0
Derivative gain (loss)	14,000
Cheniere Energy Investments, LLC [Member] | LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative gain (loss)		(265,000)	(394,000)	599,000
Sabine Pass Liquefaction [Member] | LNG Inventory Derivatives [Member]
Derivative [Line Items]
Derivative gain (loss)	201,000	0	976,000	0
Cheniere Marketing, LLC [Member] | Fuel Derivatives [Member]
Derivative [Line Items]
Derivative gain (loss)	(57,000)	0	(57,000)	0
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0		0		0
Not Designated as Hedging Instrument [Member] | Sabine Pass Liquefaction [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	0		0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative gain (loss) in Other Comprehensive Income	0	(29,676,000)	21,297,000	(29,676,000)
Derivative, Collateral, Right to Reclaim Cash					0
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0	0	0
Derivative gain (loss) recognized in income (ineffective portion and amount excluded from Effectiveness Testing)	0	0	(5,806,000)	0
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax			$ (30,000)	$ 0

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Business Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Segment Reporting, Measurement Disclosures [Abstract]
Revenues	$ 67,710	$ 65,998	$ 200,793	$ 198,799
Depreciation, depletion and amortization	15,246	15,233	45,533	47,001
Income (loss) from operations	(45,876)	(54,517)	(249,608)	(59,917)
Interest expense, net	(52,528)	(45,504)	(134,806)	(159,719)
Loss before income taxes and non-controlling interest	(120,674)	(111,815)	(408,264)	(246,522)
Goodwill	76,819		76,819		76,819
Total assets	8,125,853		8,125,853		4,639,085
Cheniere Energy Partners, LP [Member]
Segment Reporting Information [Line Items]
Ownership Interest	57.90%		57.90%
LNG terminal [Member] | Corpus Christi LNG [Member]
Segment Reporting Information [Line Items]
Business segment ownership percentage	100.00%		100.00%
LNG terminal [Member] | Creole Trail LNG [Member]
Segment Reporting Information [Line Items]
Business segment ownership percentage	100.00%		100.00%
LNG terminal [Member] | Sabine Pass LNG terminal [Member]
Segment Reporting Information [Line Items]
Storage Capacity			16.9
Volume of vessel	265,000		265,000
Regasification capacity	4.0		4.0
LNG terminal business [Member]
Segment Reporting, Measurement Disclosures [Abstract]
Revenues	67,558	69,868	201,408	206,249
Intersegment revenues (losses)	(820)	(3,929)	(2,184)	(6,973)
Depreciation, depletion and amortization	14,581	14,566	43,405	43,810
Non-cash compensation	3,148	6,505	22,477	6,964
Income (loss) from operations	(49,600)	(16,446)	(103,655)	7,237
Interest expense, net	55,378	55,333	156,644	165,251
Loss before income taxes and non-controlling interest	(127,202)	(71,335)	128,441	(158,016)
Goodwill	76,819	76,819	76,819	76,819
Total assets	7,719,551	4,136,574	7,719,551	4,136,574
Expenditures for additions to long-lived assets	852,847	883,798	2,467,210	931,542
LNG terminal business [Member] | Cheniere Marketing, LLC [Member]
Segment Reporting, Measurement Disclosures [Abstract]
Proceeds (payments) of gross margin earned, percentage			80.00%
LNG and natural gas marketing business [Member]
Segment Reporting, Measurement Disclosures [Abstract]
Revenues	16,470	2,661	27,627	977
Intersegment revenues (losses)	(15,880)	(2,953)	(27,186)	(2,618)
Depreciation, depletion and amortization	251	256	751	1,815
Non-cash compensation	4,594	9,256	36,234	10,657
Income (loss) from operations	2,919	(16,462)	(39,543)	(31,788)
Interest expense, net	0	(12)	0	(12)
Loss before income taxes and non-controlling interest	2,515	418,655	(40,092)	403,369
Goodwill	0	0	0	0
Total assets	63,756	42,308	63,756	42,308
Expenditures for additions to long-lived assets	61	(6)	57	1,659
LNG and natural gas marketing business [Member] | Cheniere Marketing, LLC [Member]
Segment Reporting, Measurement Disclosures [Abstract]
Proceeds (payments) of gross margin earned, percentage			80.00%
Corporate and Other [Member]
Segment Reporting, Measurement Disclosures [Abstract]
Revenues	(16,318)	(6,531)	(28,242)	(8,427)
Intersegment revenues (losses)	16,700	6,882	29,370	9,591
Depreciation, depletion and amortization	414	411	1,377	1,376
Non-cash compensation	20,197	36,104	152,635	38,492
Income (loss) from operations	805	(21,609)	(106,410)	(35,366)
Interest expense, net	(2,850)	(9,817)	(21,838)	(5,520)
Loss before income taxes and non-controlling interest	4,013	(459,135)	(496,613)	(491,875)
Goodwill	0	0	0	0
Total assets	342,546	204,843	342,546	204,843
Expenditures for additions to long-lived assets	389	696	1,293	1,192
Consolidated Entities [Member]
Segment Reporting, Measurement Disclosures [Abstract]
Revenues	67,710	65,998	200,793	198,799
Intersegment revenues (losses)	0	0	0	0
Depreciation, depletion and amortization	15,246	15,233	45,533	47,001
Non-cash compensation	27,939	51,865	211,346	56,113
Income (loss) from operations	(45,876)	(54,517)	(249,608)	(59,917)
Interest expense, net	(52,528)	(45,504)	(134,806)	(159,719)
Loss before income taxes and non-controlling interest	(120,674)	(111,815)	(408,264)	(246,522)
Goodwill	76,819	76,819	76,819	76,819
Total assets	8,125,853	4,383,725	8,125,853	4,383,725
Expenditures for additions to long-lived assets	$ 853,297	$ 884,488	$ 2,468,560	$ 934,393

XML

Long-Term Debt - 2013 Liquefaction Credit Facility (Details) (USD $)	4 Months Ended
	Sep. 30, 2013
Sabine Pass Liquefaction [Member] | 2021 Sabine Pass Liquefaction Notes [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.625%
Sabine Pass Liquefaction [Member] | 2013 Sabine Pass Liquefaction Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of credit borrowing capacity	$ 5,900,000,000
Line of Credit Facility, Amount Outstanding	100,000,000
Liquefaction Credit Facility | 2013 Sabine Pass Liquefaction Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR
Line of Credit Facility, Collateral Fees, Amount	$ 144,000,000
Line of Credit Facility, Amortization Period	18 years
Percentage of Debt Hedged by Interest Rate Derivatives	75.00%
Liquefaction Credit Facility | 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	40.00%
Construction [Member] | Minimum [Member] | 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.30%
Construction [Member] | Maximum [Member] | 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.00%
Operations [Member] | Minimum [Member] | 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.30%
Operations [Member] | Maximum [Member] | 2013 Liquifaction Credit Facility - LIBOR Loans [Member] [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.25%

XML

Accrued Liabilities (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Accrued Liabilities, Current [Abstract]
Accrued interest expense and related fees	$ 97,758	$ 16,327
Payroll	25,693	6,369
LNG liquefaction costs	33,956	27,919
LNG terminal costs	1,650	977
Other accrued liabilities	12,958	7,145
Accrued liabilities	$ 172,015	$ 58,737

XML

Long-Term Debt - Schedule of Long Term Debt (Details) (USD $)	3 Months Ended		9 Months Ended							9 Months Ended								9 Months Ended				1 Months Ended							3 Months Ended		9 Months Ended			9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013 2012 Liquefaction Credit Facility [Member]	Dec. 31, 2012 2012 Liquefaction Credit Facility [Member]	Sep. 30, 2013 Creole Trail Pipeline Credit Facility [Member]	Dec. 31, 2012 Creole Trail Pipeline Credit Facility [Member]	Sep. 30, 2012 Senior Notes	Sep. 30, 2013 Senior Notes Long-term Debt Discount [Member]	Dec. 31, 2012 Senior Notes Long-term Debt Discount [Member]	Sep. 30, 2013 Liquefaction Credit Facility 2012 Liquefaction Credit Facility [Member]	Sep. 30, 2013 Liquefaction Credit Facility 2013 Sabine Pass Liquefaction Credit Facility [Member]	Sep. 30, 2013 Cheniere Creole Trail Pipeline LP [Member] Creole Trail Pipeline Credit Facility [Member]	Dec. 31, 2012 Cheniere Creole Trail Pipeline LP [Member] Creole Trail Pipeline Credit Facility [Member]	Sep. 30, 2013 Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Sabine Pass Liquefaction [Member] 2021 Sabine Pass Liquefaction Notes [Member] Rate	Dec. 31, 2012 Sabine Pass Liquefaction [Member] 2021 Sabine Pass Liquefaction Notes [Member]	Sep. 30, 2013 Sabine Pass Liquefaction [Member] Sabine Pass Liquefaction Notes due 2023 [Member]	Dec. 31, 2012 Sabine Pass Liquefaction [Member] Sabine Pass Liquefaction Notes due 2023 [Member]	Apr. 30, 2013 Sabine Pass Liquefaction [Member] 2012 Liquefaction Credit Facility [Member]	Sep. 30, 2013 Sabine Pass Liquefaction [Member] 2013 Sabine Pass Liquefaction Credit Facility [Member]	Dec. 31, 2012 Sabine Pass Liquefaction [Member] 2013 Sabine Pass Liquefaction Credit Facility [Member]	Sep. 30, 2013 Sabine Pass LNG, LP [Member] 2016 Senior Notes [Member]	Dec. 31, 2012 Sabine Pass LNG, LP [Member] 2016 Senior Notes [Member]	Sep. 30, 2013 Sabine Pass LNG, LP [Member] 2020 Notes	Dec. 31, 2012 Sabine Pass LNG, LP [Member] 2020 Notes	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes	Sep. 30, 2012 Sabine Pass LNG, LP [Member] Senior Notes	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes Rate	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes 2016 Senior Notes [Member]	Dec. 31, 2012 Sabine Pass LNG, LP [Member] Senior Notes 2016 Senior Notes [Member]	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes 2020 Notes	Dec. 31, 2012 Sabine Pass LNG, LP [Member] Senior Notes 2020 Notes
Debt Instrument [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives													75.00%	75.00%
Debt Instrument, Interest Rate, Stated Percentage																		5.625%							7.50%	7.50%	6.50%	6.50%
Redemption of Debt Instrument, Percentage																																		35.00%
Redemption Premium																		$ 1																$ 1.065
Line of Credit Facility, Increase (Decrease) for Period, Net																						1,400,000,000
Gains (Losses) on Extinguishment of Debt	0	0	(80,510,000)	(15,098,000)
Percentage if 2020 Notes Outstanding																																		65.00%
Debt instrument fixed charge coverage ratio																		1.25													2
Debt discount								8,336,000	0		14,866,000	18,387,000			(10,000,000)
Debt Instrument, Unamortized Premium					0												11,897,000
Long-term debt (including related parties)	5,585,500,000		5,585,500,000		2,185,500,000	0	100,000,000								400,000,000	0		2,000,000,000	0	1,000,000,000	0		100,000,000	0								1,665,500,000	1,665,500,000	420,000,000	420,000,000
Total long-term debt, (including related parties), net of discount	5,574,195,000		5,574,195,000		2,167,113,000
Distribution Made to Member or Limited Partner, Cash Distributions Paid										$ 182,900,000																			$ 93,000,000	$ 36,200,000	$ 242,100,000

XML

Variable Interest Entity

9 Months Ended

Sep. 30, 2013

Variable Interest Entity [Abstract]

Variable Interest Entities

VARIABLE INTEREST ENTITY

Cheniere Energy Partners

Cheniere Partners is a master limited partnership formed by us to own and operate the Sabine Pass LNG terminal and related assets. As of September 30, 2013, we owned 57.9% of Cheniere Partners in the form of 12.0 million common units, 45.3 million Class B units, 135.4 million subordinated units and a 2% general partner interest. Cheniere Energy Partners GP, LLC ("Cheniere Partners GP"), our wholly owned subsidiary, is the general partner of Cheniere Partners. In May 2012, Cheniere Partners, Cheniere and Blackstone entered into the Blackstone Unit Purchase Agreement whereby Cheniere Partners agreed to sell to Blackstone in a private placement 100.0 million Class B units at a price of $15.00 per Class B unit. In August 2012, all conditions to funding were met and Blackstone purchased its initial 33.3 million Class B units, and as of December 31, 2012, Blackstone had purchased the remaining 66.7 million Class B units. At initial funding, the board of directors of Cheniere Partners GP was modified to include three directors appointed by Blackstone, four directors appointed by us and four independent directors mutually agreed by Blackstone and us and appointed by us. In addition, we have provided Blackstone with a right to maintain one board seat on our board of directors. A quorum consists of a majority of all directors, including at least two directors appointed by Blackstone, two directors appointed by us and two independent directors. Blackstone will no longer be entitled to appoint directors in the event that Blackstone's ownership in Cheniere Partners is less than: (i) 20% of outstanding common units, subordinated units and Class B units, and (ii) 50.0 million Class B units.

As a result of contractual changes in the governance of Cheniere Partners GP in connection with the Blackstone Unit Purchase Agreement, we have determined that Cheniere Partners GP is a variable interest entity and that we, as the holder of the equity at risk, do not have a controlling financial interest due to the rights held by Blackstone. However, we continue to consolidate Cheniere Partners as a result of Blackstone's right to maintain one board seat on our board of directors which creates a de facto agency relationship between Blackstone and us. GAAP requires that when a de facto agency relationship exists, one of the members of the de facto agency relationship must consolidate the variable interest entity based on certain criteria. As a result, we consolidate Cheniere Partners in our consolidated financial statements.

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Restricted Cash and Cash Equivalents (Details) (USD $)												9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013 Other Contractual Restrictions [Member]	Dec. 31, 2012 Other Contractual Restrictions [Member]	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Senior Notes Interest Payments [Member]	Dec. 31, 2012 Sabine Pass LNG, LP [Member] Senior Notes Interest Payments [Member]	Sep. 30, 2013 Sabine Pass LNG, LP [Member] Debt Service Reserve Fund [Member]	Dec. 31, 2012 Sabine Pass LNG, LP [Member] Debt Service Reserve Fund [Member]	Sep. 30, 2013 Cheniere Creole Trail Pipeline LP [Member]	Sep. 30, 2013 Sabine Pass LNG and Cheniere Partners [Member] Cheniere Energy, Inc. [Member]	Dec. 31, 2012 Sabine Pass LNG and Cheniere Partners [Member] Cheniere Energy, Inc. [Member]	Sep. 30, 2013 Senior Notes Sabine Pass LNG, LP [Member] Rate	Sep. 30, 2013 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Jul. 31, 2012 2012 Liquefaction Credit Facility [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 2020 Notes Sabine Pass LNG, LP [Member]	Dec. 31, 2012 2020 Notes Sabine Pass LNG, LP [Member]	Sep. 30, 2013 2020 Notes Senior Notes Sabine Pass LNG, LP [Member]	Dec. 31, 2012 2020 Notes Senior Notes Sabine Pass LNG, LP [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Senior Secured Notes Due 2021 [Member] Senior Notes Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Sabine Pass Liquefaction Notes due 2023 [Member] Sabine Pass Liquefaction [Member]	Sep. 30, 2013 Sabine Pass Liquefaction Notes due 2023 [Member] Senior Notes Sabine Pass Liquefaction [Member]	Sep. 30, 2013 2016 Senior Notes [Member] Sabine Pass LNG, LP [Member]	Dec. 31, 2012 2016 Senior Notes [Member] Sabine Pass LNG, LP [Member]	Sep. 30, 2013 Payment of Liabilities [Member] Sabine Pass Liquefaction [Member] Debt Service Reserve Fund [Member]	Dec. 31, 2012 Payment of Liabilities [Member] Sabine Pass Liquefaction [Member] Debt Service Reserve Fund [Member]	Sep. 30, 2013 Payment For Project [Member] Sabine Pass Liquefaction [Member] Debt Service Reserve Fund [Member]	Dec. 31, 2012 Payment For Project [Member] Sabine Pass Liquefaction [Member] Debt Service Reserve Fund [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Principal amount of private offerings consummated																	$ 420,000,000	$ 420,000,000	$ 500,000,000	$ 2,000,000,000	$ 2,000,000,000	$ 1,000,000,000	$ 1,000,000,000	$ 1,665,500,000	$ 166,500,000
Debt Instrument, Interest Rate, Stated Percentage															6.50%	6.50%								7.50%	7.50%
Debt Instrument, Fixed Charge, Coverage Ratio												2
Line of credit borrowing capacity													5,900,000,000	3,600,000,000
Current restricted cash and cash equivalents	577,945,000	520,263,000	28,000,000	8,500,000	53,000,000	17,400,000			23,500,000	339,900,000	419,300,000															133,500,000	75,100,000
Non-current restricted cash and cash equivalents	$ 828,858,000	$ 272,924,000	$ 500,000				$ 76,100,000	$ 76,100,000	$ 87,200,000																			$ 665,100,000	$ 196,300,000

XML

Financial Instruments - Fair Value of Derivative Assets and Liabilities (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Right to Reclaim Cash	$ 6,100	$ 5,900
LNG Inventory Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Asset, Fair Value, Net	186	237
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Current	0	0
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Current	186	237
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Current	0	0
LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Current	186	237
Fuel Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net	0	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Fuel Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Current	(283)	(98)
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Current	0	0
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Current	0	0
Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Current	(283)	(98)
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net		0
Derivative Asset, Fair Value, Net	0
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net		(26,424)
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net		0
Derivative Asset, Fair Value, Net	0
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net		(26,424)
Other Liabilities [Member] | LNG Inventory Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Current	186
Other Liabilities [Member] | Fuel Derivatives [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Current		(98)
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Net	(8,270)	(5,134)
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Asset, Fair Value, Net	64,309
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Net	56,039
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Net	$ 56,039

XML

Financial Instruments

9 Months Ended

Sep. 30, 2013

Financial Instruments [Abstract]

Financial Instruments

FINANCIAL INSTRUMENTS

Derivative Instruments

We have entered into certain instruments to hedge the exposure to variability in expected future cash flows attributable to the future sale of our LNG inventory ("LNG Inventory Derivatives") and to hedge the exposure to price risk attributable to future purchases of natural gas to be utilized as fuel to operate the Sabine Pass LNG terminal ("Fuel Derivatives"), and interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2013 Liquefaction Credit Facilities ("Interest Rate Derivatives").

The following table (in thousands) shows the fair value of our derivative assets and liabilities that are required to be measured at fair value on a recurring basis as of September 30, 2013 and December 31, 2012, which are classified as other current assets, other current liabilities and other non-current liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	September 30, 2013										December 31, 2012
	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
LNG Inventory Derivatives asset	$	—	$	186		$	—	$	186		$	—	$	237		$	—	$	237
Fuel Derivatives (liability)	—		(283		)	—		(283		)	—		(98		)	—		(98		)
Interest Rate Derivatives asset (liability)	—		56,039			—		56,039			—		(26,424		)	—		(26,424		)

The estimated fair values of our LNG Inventory Derivatives and Fuel Derivatives are the amount 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. 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 derivative instruments that qualify for derivative accounting treatment as either assets or liabilities and measure those instruments at fair value.  For those instruments accounted for as derivatives, including our LNG Inventory Derivatives and certain of our Fuel Derivatives, changes in fair value are reported in earnings.

The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances where our Fuel Derivatives or our LNG Inventory Derivatives are in an asset position. Our commodity derivative transactions 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 commodity derivative activities.  Collateral of $6.1 million and $5.9 million deposited for such contracts, which has not been reflected in the derivative fair value tables, is included in the other current assets balance as of September 30, 2013, and December 31, 2012, respectively.

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

		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2013			December 31, 2012
LNG Inventory Derivatives asset	Prepaid expenses and other	$	186		$	237
Fuel Derivatives (liability)	Prepaid expenses and other	(283		)	(98		)

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in marketing and trading revenues (losses) on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
LNG Inventory Derivatives gain (loss)	$	14		$	(265	)	$	(394	)	$	599
Fuel Derivatives loss	(57		)	—			(57		)	—

The following table (in thousands) shows the changes in the fair value and settlements of our LNG Inventory Derivatives and Fuel Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013			2012		2013			2012
LNG Inventory Derivatives gain	$	201		$	—	$	976		$	—
Fuel Derivatives gain (loss)	(55		)	287		(3		)	(288		)

Interest Rate Derivatives

In August 2012 and June 2013, Sabine Pass Liquefaction entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2012 Liquefaction Credit Facility and the 2013 Liquefaction Credit Facilities, respectively. The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2013 Liquefaction Credit Facilities.

Sabine Pass Liquefaction designated the Interest Rate Derivatives entered into in August 2012 as hedging instruments which was required in order to qualify for cash flow hedge accounting. As a result of this cash flow hedge designation, we recognized the Interest Rate Derivatives entered into in August 2012 as an asset or liability at fair value, and reflected changes in fair value through other comprehensive income in our Consolidated Statements of Comprehensive Loss. Any hedge ineffectiveness associated with the Interest Rate Derivatives entered into in August 2012 was recorded immediately as derivative gain (loss) in our Consolidated Statements of Operations. The realized gain (loss) on the Interest Rate Derivatives entered into in August 2012 was recorded as an (increase) decrease in interest expense on our Consolidated Statements of Operations to the extent not capitalized as part of the Liquefaction Project. The effective portion of the gains or losses on our Interest Rate Derivatives entered into in August 2012 recorded in other comprehensive income would have been reclassified to earnings as interest payments on the 2012 Liquefaction Credit Facility impact earnings. In addition, amounts recorded in other comprehensive income are also reclassified into earnings if it becomes probable that the hedged forecasted transaction will not occur.

Sabine Pass Liquefaction did not elect to designate the Interest Rate Derivatives entered into in June 2013 as cash flow hedging instruments, and changes in fair value are recorded as derivative gain (loss), net within the Consolidated Statements of Operations.

During the first quarter of 2013, we determined that it was no longer probable that the forecasted variable interest payments on the 2012 Liquefaction Credit Facility would occur in the time period originally specified based on the continued development of our financing strategy for the Liquefaction Project, and, in particular, the Sabine Pass Liquefaction Senior Notes described in Note 8—"Long-Term Debt". As a result, all of the Interest Rate Derivatives entered into in August 2012 were no longer effective hedges, and the remaining portion of hedge relationships that were designated cash flow hedges as of December 31, 2012, were de-designated as of February 1, 2013. For de-designated cash flow hedges, changes in fair value prior to their de-designation date were recorded as other comprehensive income (loss) within the Consolidated Balance Sheets, and changes in fair value subsequent to their de-designation date were recorded as derivative gain (loss) within the Consolidated Statements of Operations.

In June 2013, we concluded that the hedged forecasted transactions associated with the Interest Rate Derivatives entered into in connection with the 2012 Liquefaction Credit Facility had become probable of not occurring based on the issuances of the Sabine Pass Liquefaction Senior Notes, the closing of the 2013 Liquefaction Credit Facilities, the additional Interest Rate Derivatives executed in June 2013, and our intention to continue to issue fixed rate debt to refinance drawn portions of the 2013 Liquefaction Credit Facilities. As a result, the amount remaining in accumulated other comprehensive income ("AOCI") pertaining to the previously designated Interest Rate Derivatives was reclassified out of AOCI and into income. We have presented the reclassification of unrealized losses from AOCI into income and the changes in fair value and settlements subsequent to the reclassification date separate from interest expense as derivative gain (loss), net in our Consolidated Statements of Operations.

At September 30, 2013, Sabine Pass Liquefaction 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
Interest Rate Derivatives - Not Designated	$20.0 million	$2.9 billion	August 14, 2012	July 31, 2019	1.98%	One-month LIBOR
Interest Rate Derivatives - Not Designated	—	$671.0 million	June 5, 2013	May 28, 2020	2.05%	One-month LIBOR

The following table (in thousands) shows the fair value of our Interest Rate Derivatives:

		Fair Value Measurements as of
	Balance Sheet Location	September 30, 2013		December 31, 2012
Interest Rate Derivatives - Not Designated	Non-current derivative assets	$	64,309	$	—
Interest Rate Derivatives - Designated	Non-current derivative liabilities	—		21,290
Interest Rate Derivatives - Not Designated	Other current liabilities	8,270		—
Interest Rate Derivatives - Not Designated	Non-current derivative liabilities	—		5,134

The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the three months ended September 30, 2013 and 2012:

	Gain (Loss) in Other Comprehensive Income					Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	2013		2012			2013		2012		2013		2012
Interest Rate Derivatives - Designated	$	—	$	(29,676	)	$	—	$	—	$	—	$	—

The following table (in thousands) details the effect of our Interest Rate Derivatives included in OCI and AOCI for the nine months endedSeptember 30, 2013 and 2012:

	Gain (Loss) in Other Comprehensive Income						Gain (Loss) Reclassified from AOCI into Interest Expense (Effective Portion)				Losses Reclassified into Earnings as a Result of Discontinuance of Cash Flow Hedge Accounting
	2013			2012			2013		2012		2013			2012
Interest Rate Derivatives - Designated	$	21,297		$	(29,676	)	$	—	$	—	$	(5,806	)	$	—
Interest Rate Derivatives - Settlements	(30		)	—			—		—		(167		)	—

The following table (in thousands) shows the changes in the fair value of our Interest Rate Derivatives - Not Designated recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013			2012		2013		2012
Interest Rate Derivatives - Not Designated gain (loss)	$	(22,481	)	$	—	$	60,707	$	—

Balance Sheet Presentation

Our commodity 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 Sheet			Net Amounts Presented in the Consolidated Balance Sheet			Gross Amounts Not Offset in the Consolidated Balance Sheet
Offsetting Derivative Assets (Liabilities)										Derivative Instrument		Cash Collateral Received (Paid)		Net Amount
As of September 30, 2013:
Fuel Derivatives	$	(283	)	$	(283	)	$	—		$	—	$	—	$	—
LNG Inventory Derivatives	186						186			—		—		186
Interest Rate Derivatives - Not Designated	64,309			—			64,309			—		—		64,309
Interest Rate Derivatives - Not Designated	(8,270		)	—			(8,270		)	—		—		(8,270		)
As of December 31, 2012:
Fuel Derivatives	(98		)	(98		)	—			—		—		—
LNG Inventory Derivatives	237			—			237			—		—		237
Interest Rate Derivatives - Designated	(21,290		)	—			(21,290		)	—		—		(21,290		)
Interest Rate Derivatives - Not Designated	(5,134		)	—			(5,134		)	—		—		(5,134		)

Other Financial Instruments

The estimated fair value of our other financial instruments, including those financial instruments for which the fair value option was not elected, are set forth in the table below.  The carrying amounts reported on our Consolidated Balance Sheets for cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, interest receivable and accounts payable approximate fair value due to their short-term nature.

Other Financial Instruments (in thousands):

	September 30, 2013				December 31, 2012
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 Notes, net of discount (1)	$	1,650,634	$	1,811,570	$	1,647,113	$	1,824,177
2020 Notes (1)	420,000		425,250		420,000		437,850
2021 Sabine Pass Liquefaction Senior Notes (1)	2,011,897		1,951,540		—		—
2023 Sabine Pass Liquefaction Senior Notes (1)	1,000,000		952,500		—		—
2012 Liquefaction Credit Facility (2)	—		—		100,000		100,000
2013 Liquefaction Credit Facilities (2)	100,000		100,000		—		—
CTPL Credit Facility (3)	391,665		400,000		—		—

(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 September 30, 2013 and December 31, 2012, as applicable.

(2) The Level 3 estimated fair value approximates the carrying amount because the interest rates are variable and reflective of market rates and Sabine Pass Liquefaction has the ability to call this debt at anytime without penalty.

(3) The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and CTPL has the ability to call this debt at anytime without penalty.

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Non-Controlling Interest

9 Months Ended

Sep. 30, 2013

Noncontrolling Interest [Abstract]

Noncontrolling Interest

NON-CONTROLLING INTEREST

Cheniere Partners financial statements are consolidated in our consolidated financial statements and we record the partnership's other partners' equity as a non-controlling interest. The following table sets forth the components of our non-controlling interest balance since inception attributable to third-party investors’ interests at September 30, 2013 (in thousands): 

Net proceeds from Cheniere Partners’ issuance of common units (1)	$	719,572
Net proceeds from CLNGH’s sale of Cheniere Partners common units (2)	203,946
Distributions to Cheniere Partners’ non-controlling interest	(207,396		)
Net proceeds from Cheniere Partners' issuance of Class B units (3)	1,387,339
Non-controlling interest share of loss of Cheniere Partners	(76,325		)
Non-controlling interest at September 30, 2013	$	2,027,136

(1) In March and April 2007, we and Cheniere Partners completed a public offering of 15.5 million Cheniere Partners common units (the "Cheniere Partners IPO"). Cheniere Partners received $98.4 million in net proceeds from the issuance of its common units to the public.

In January 2011, Cheniere Partners initiated an at-the-market program to sell up to 1.0 million common units, the proceeds from which would be used primarily to fund development costs associated with the Liquefaction Project. As of December 31, 2011, Cheniere Partners had sold 0.5 million common units with net proceeds of $9.0 million. During the year endedDecember 31, 2012, Cheniere Partners sold 0.5 million common units with net proceeds of $11.1 million.

In September 2011, Cheniere Partners sold 3.0 million common units in an underwritten public offering and 1.1 million common units to Cheniere Common Units Holding, LLC, a wholly owned subsidiary of Cheniere, at a price of $15.25 per common unit. Cheniere Partners received net proceeds of $43.3 million and $16.4 million from the public offering and Cheniere Common Units Holding, LLC sale, respectively.

In September 2012, Cheniere Partners sold 8.0 million common units in an underwritten public offering at a price of $25.07 per common unit for net cash proceeds of $194.0 million.

In March 2013, Cheniere Partners sold 17.6 million common units in a registered direct offering to institutional investors at a price of $20.75 per common unit for net proceeds of $364.8 million.

(2) In conjunction with the Cheniere Partners IPO, Cheniere LNG Holdings, LLC ("CLNGH") sold a portion of the Cheniere Partners common units held by it to the public, realizing net proceeds of $203.9 million, which included $39.4 million of net proceeds realized once the underwriters exercised their option to purchase an additional 2.0 million common units from Holdings.

(3) In May 2012, Cheniere Partners, Cheniere and Blackstone CQP Holdco LP ("Blackstone") entered into a unit purchase agreement (the "Blackstone Unit Purchase Agreement") whereby Cheniere Partners agreed to sell to Blackstone in a private placement 100.0 million Class B units of Cheniere Partners ("Class B units") at a price of $15.00 per Class B unit. Cheniere Partners had issued and sold all 100.0 million Class B units to Blackstone as of December 31, 2012. See Note 5—"Variable Interest Entity".

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	9 Months Ended		79 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013
Cash flows from operating activities
Net loss attributable to common stockholders	$ (372,692)	$ (238,456)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization	45,533	47,001
Loss on early extinguishment of debt	80,510	15,095
Amortization of debt issuance and discount costs	8,590	18,073
Non-cash compensation	202,785	53,961
Non-cash LNG inventory write-downs	27,851	9,763
Non-cash derivative (gain) loss, net	(55,053)	698
Net loss attributable to non-controlling interest	(38,323)	(8,277)
Use of restricted cash and cash equivalents	113,626	24,139
Crest royalty	0	(13,384)
Other	(2,622)	(2,715)
Changes in operating assets and liabilities:
Accounts and interest receivable	(21,514)	(23,871)
Accounts payable and accrued liabilities	55,043	19,413
LNG inventory, net	(29,071)	(6,308)
Deferred revenue	(2,955)	(3,104)
Prepaid expenses and other	(34,011)	2,993
Net cash used in operating activities	(22,303)	(104,979)
Cash flows from investing activities
LNG terminal and pipeline costs, net	(2,448,690)	(871,167)
Use of restricted cash and cash equivalents	2,466,613	1,352,656
Investment in Cheniere Partners	(11,122)	(534,940)
Other	(26,471)	(21,596)
Net cash provided by (used in) investing activities	(19,670)	(75,047)
Cash flows from financing activities
Proceeds from Sabine Pass Liquefaction Senior Notes, net	3,012,500	0
Proceeds from CTPL Credit Facility, net	391,978	0
Proceeds from sale of common units by Cheniere Partners	364,775	205,174
Proceeds from 2013 Liquefaction Credit Facility	100,000	0
Proceeds from sale of common stock, net	274	1,200,717
Proceeds from sales of Class B units by Cheniere Partners	(3)	887,563	1,387,339	[1]
Investments in restricted cash and cash equivalents	(3,182,735)	(1,425,209)
Repurchases and prepayments of debt	0	(776,514)
Debt issuance and deferred financing costs	(235,250)	(210,828)
Proceeds from (repayments of) 2012 Liquefaction Credit Facility	100,000	100,000
Distributions to non-controlling interest	(50,046)	(24,628)
Purchase of treasury shares	(89,137)	(20,414)
Excess tax benefit from stock-based compensation	2,070	0
Net cash provided by used in financing activities	214,426	(64,139)
Net increase (decrease) in cash and cash equivalents	172,453	(244,165)
Cash and cash equivalents—beginning of period	201,711	459,160
Cash and cash equivalents—end of period	$ 374,164	$ 214,995	$ 374,164

[1] In May 2012, Cheniere Partners, Cheniere and Blackstone CQP Holdco LP ("Blackstone") entered into a unit purchase agreement (the "Blackstone Unit Purchase Agreement") whereby Cheniere Partners agreed to sell to Blackstone in a private placement 100.0 million Class B units of Cheniere Partners ("Class B units") at a price of $15.00 per Class B unit. Cheniere Partners had issued and sold all 100.0 million Class B units to Blackstone as of December 31, 2012. See Note 5—"Variable Interest Entity".

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Net Loss Per Share Attributable to Common Stockholders (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average number of common shares outstanding - basic and diluted	220,734,000	208,712,000	217,940,000	170,414,000
Weighted average common shares outstanding - Basic		208,712,000		170,414,000
Weighted average common shares outstanding - Common stock options	0	0	0	0
Weighted average common shares outstanding - Diluted	$ 220,734,000	$ 208,712,000	$ 217,940,000	$ 170,414,000
basic and diluted net loss per share attributable to common stockholders (US$ per share)	$ (0.46)	$ (0.52)	$ (1.71)	$ (1.40)
Stock options, warrants and unvested stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	18,300,000	5,600,000	16,500,000	3,100,000

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Financial Instruments - Interest Rate Derivatives Market Adjustments (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax	$ 0	$ 0	$ (30)	$ 0
Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net			0	0
Derivative gain (loss) recognized in income (ineffective portion and amount excluded from Effectiveness Testing)			(167)	0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss) in Other Comprehensive Income	0	(29,676)	21,297	(29,676)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	0	0	0
Derivative gain (loss) recognized in income (ineffective portion and amount excluded from Effectiveness Testing)	0	0	(5,806)	0
Other Comprehensive Income (Loss), Reclassification Adjustment on Derivatives Included in Net Income, Net of Tax			(30)	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ (22,481)	$ 0	$ 60,707	$ 0

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Non-Controlling Interest (Details) (USD $) Share data in Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended		1 Months Ended	3 Months Ended	79 Months Ended				1 Months Ended			3 Months Ended	12 Months Ended		6 Months Ended	1 Months Ended				8 Months Ended	1 Months Ended	3 Months Ended	8 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Apr. 30, 2007 Cheniere Energy Partners, LP [Member]	Mar. 31, 2013 Cheniere Energy Partners, LP [Member]	Sep. 30, 2013 Cheniere Energy Partners, LP [Member]		Sep. 30, 2013 Cheniere LNG Holdings [Member]		Sep. 30, 2011 common units [Member]	Sep. 30, 2012 common units [Member] Cheniere Energy Partners, LP [Member]	Sep. 30, 2011 common units [Member] Cheniere Energy Partners, LP [Member]	Mar. 31, 2013 common units [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 common units [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2011 common units [Member] Cheniere Energy Partners, LP [Member]	Jun. 30, 2013 common units [Member] Cheniere Common Units Holding, LLC [Member]	Apr. 30, 2007 common units [Member] Cheniere LNG Holdings [Member]	Sep. 30, 2011 common units [Member] Common Unit Purchase Option [Member] Cheniere LNG Holdings [Member]	Apr. 30, 2007 common units [Member] Common Unit Purchase Option [Member] Cheniere LNG Holdings [Member]	May 31, 2012 Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Aug. 31, 2012 Blackstone CQP Holdco LP [Member] Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 Blackstone CQP Holdco LP [Member] Class B Unit [Member] Cheniere Energy Partners, LP [Member]	Dec. 31, 2012 Blackstone CQP Holdco LP [Member] Class B Unit [Member] Cheniere Energy Partners, LP [Member]
Noncontrolling Interest [Line Items]
Proceeds from Issuance or Sale of Equity															$ 11,100,000	$ 9,000,000
Stockholders' Equity Attributable to Noncontrolling Interest [Abstract]
Net proceeds fromCheniere Partners' issuance of common units							719,572,000	[1]	203,946,000	[2]
Distributions to Cheniere Partners' non-controlling interest			(50,046,000)				(207,396,000)
Non-controlling interest	21,659,000	2,875,000	38,323,000	8,277,000			76,325,000
Partners' Capital Account, Units, Sold in Public Offering					15.5								3.0		8.0				1.1	2.0
Proceeds from sale of common units by Cheniere Partners			364,775,000	205,174,000	98,400,000										194,000,000	43,300,000		203,900,000	16,400,000	39,400,000
Number of units authorized for sale under issuance program																1.0
Number of common units sold as part of program															0.5	0.5
Common units sold in private placement														17.6								100.0	33.3	66.7	100.0
Price per Common Unit											$ 15.25	$ 25.07					$ 20.75				$ 15.00
Proceeds from sale of common stock, net			$ 274,000	$ 1,200,717,000		$ 364,800,000

[1] In March and April 2007, we and Cheniere Partners completed a public offering of 15.5 million Cheniere Partners common units (the "Cheniere Partners IPO"). Cheniere Partners received $98.4 million in net proceeds from the issuance of its common units to the public.In January 2011, Cheniere Partners initiated an at-the-market program to sell up to 1.0 million common units, the proceeds from which would be used primarily to fund development costs associated with the Liquefaction Project. As of December 31, 2011, Cheniere Partners had sold 0.5 million common units with net proceeds of $9.0 million. During the year ended December 31, 2012, Cheniere Partners sold 0.5 million common units with net proceeds of $11.1 million. In September 2011, Cheniere Partners sold 3.0 million common units in an underwritten public offering and 1.1 million common units to Cheniere Common Units Holding, LLC, a wholly owned subsidiary of Cheniere, at a price of $15.25 per common unit. Cheniere Partners received net proceeds of $43.3 million and $16.4 million from the public offering and Cheniere Common Units Holding, LLC sale, respectively.In September 2012, Cheniere Partners sold 8.0 million common units in an underwritten public offering at a price of $25.07 per common unit for net cash proceeds of $194.0 million. In March 2013, Cheniere Partners sold 17.6 million common units in a registered direct offering to institutional investors at a price of $20.75 per common unit for net proceeds of $364.8 million.

[2] In conjunction with the Cheniere Partners IPO, Cheniere LNG Holdings, LLC ("CLNGH") sold a portion of the Cheniere Partners common units held by it to the public, realizing net proceeds of $203.9 million, which included $39.4 million of net proceeds realized once the underwriters exercised their option to purchase an additional 2.0 million common units from Holdings.

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Share-Based Compensation

9 Months Ended

Sep. 30, 2013

Share-based Compensation [Abstract]

Share-based Compensation

SHARE-BASED COMPENSATION

We have granted options to purchase common stock to employees, consultants and outside directors 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"), and 2011 Incentive Plan, as amended (the "2011 Plan"). We recognize our share-based payments to employees in the consolidated financial statements based on their fair values at the date of grant. The calculated fair value is recognized as expense (net of any capitalization) over the requisite service period, net of estimated forfeitures, using the straight-line or accelerated recognition methods.

For the three months ended September 30, 2013 and 2012, the total share-based compensation expense recognized in our net loss (net of capitalization) was $26.7 million and $49.8 million, respectively. For the nine months endedSeptember 30, 2013 and 2012, the total share-based compensation expense recognized in our net loss (net of capitalization) was $202.8 million and $54.0 million, respectively.  For the three months ended September 30, 2013 and 2012, the total share-based compensation cost capitalized as part of the cost of capital assets was $1.3 million and $2.2 million, respectively. For the nine months endedSeptember 30, 2013 and 2012, the total share-based compensation cost capitalized as part of the cost of capital assets was $8.6 million and $2.2 million, respectively.

The total unrecognized compensation cost at September 30, 2013 relating to non-vested share-based compensation arrangements granted under the 1997 Plan, 2003 Plan and 2011 Plan was $283.7 million. That cost is expected to be recognized over 5.5 years, with a weighted average period of 3.4 years.

We received $0.3 million of proceeds from the exercise of stock options in the three and nine months ended September 30, 2013 and $0.8 million of proceeds from the exercise of stock options in the three and nine months ended September 30, 2012.

Long-Term Commercial Bonus Awards for Train 3 and Train 4 under the 2011-2013 Bonus Plan

On December 12, 2012, pursuant to the 2011-2013 Bonus Plan, the Compensation Committee approved a Long-Term Bonus Pool for 2012 for all employees of the Company consisting of a total of 18 million shares of restricted stock. The Long-Term Commercial Bonus Awards for Train 3 and Train 4 of the Liquefaction Project were granted to employees in February 2013 under the 2003 Plan and 2011 Plan. A portion of each employee's Long-Term Commercial Bonus Award for Train 3 and Train 4 of the Liquefaction Project was granted as a milestone award ("Milestone Award"), with vesting of the Milestone Award conditional on certain performance milestones relating to financing and constructing Train 3 and Train 4 of the Liquefaction Project, and a portion was granted as a stock price award ("Stock Price Award"), with vesting of the Stock Price Award conditional on the achievement of minimum average Company stock price hurdles.

On May 22, 2013, the $25 stock price hurdle was achieved. Following certification by a subcommittee of the compensation committee, fifty percent (50%) of the Stock Price Awards vested. The remaining Stock Price Awards will vest if the average 120-day closing stock price of the Company is $35.

On May 28, 2013, the first performance milestone was achieved when Sabine Pass Liquefaction closed the financing, and issued notice to proceed with construction under the engineering, procurement and construction contract for the construction of Train 3 and Train 4 of the Liquefaction Project (the "EPC Contract (Train 3 and Train 4)"). Following certification of the achievement of the performance milestone by a subcommittee of the compensation committee, thirty percent (30%) of the Milestone Awards vested. The remaining Milestone Awards will vest based on the achievement of the following performance milestones:

• 20% upon payment of 60% of the original contract price of the EPC Contract (Train 3 and Train 4);

• 20% upon substantial completion, as defined in the EPC Contract (Train 3 and Train 4), of Train 4 of the Liquefaction Project; and

• 30% on the first anniversary of substantial completion of Train 4 of the Liquefaction Project.

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Long-Term Debt

9 Months Ended

Sep. 30, 2013

Debt Disclosure [Abstract]

Long-term Debt

As of September 30, 2013 and December 31, 2012, our long-term debt consisted of the following (in thousands): 

	September 30,			December 31,
	2013			2012
Long-term debt
2016 Notes	$	1,665,500		$	1,665,500
2020 Notes	420,000			420,000
2021 Sabine Pass Liquefaction Senior Notes	2,000,000			—
2023 Sabine Pass Liquefaction Senior Notes	1,000,000			—
2012 Liquefaction Credit Facility	—			100,000
2013 Liquefaction Credit Facilities	100,000			—
CTPL Credit Facility	400,000			—
Total long-term debt	5,585,500			2,185,500
Long-term debt premium (discount)
2016 Notes	(14,866		)	(18,387		)
2021 Sabine Pass Liquefaction Senior Notes	11,897			—
CTPL Credit Facility	(8,336		)	—
Total long-term debt, net	$	5,574,195		$	2,167,113

Sabine Pass LNG Senior Notes

As of September 30, 2013 and December 31, 2012, Sabine Pass LNG had an aggregate principal amount of $1,665.5 million, before discount, of the 2016 Notes and $420.0 million of the 2020 Notes outstanding. Borrowings under the 2016 Notes and 2020 Notes bear interest at a fixed rate of 7.50% and 6.50%, respectively. The terms of the 2016 Notes and the 2020 Notes are substantially similar. Interest on the 2016 Notes is payable semi-annually in arrears on May 30 and November 30 of each year. Interest on the 2020 Notes is payable semi-annually in arrears on May 1 and November 1 of each year. Subject to permitted liens, the Sabine Pass LNG Senior Notes are secured on a first-priority basis by a security interest in all of Sabine Pass LNG's equity interests and substantially all of its operating assets.

Sabine Pass LNG may redeem some or all of its 2016 Notes at any time, and from time to time, at the redemption prices specified in the indenture governing the 2016 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may redeem all or part of its 2020 Notes at any time on or after November 1, 2016, at fixed redemption prices specified in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass LNG may also, at its option, redeem all or part of the 2020 Notes at any time prior to November 1, 2016, at a "make-whole" price set forth in the indenture governing the 2020 Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, Sabine Pass LNG may redeem up to 35% of the aggregate principal amount of the 2020 Notes at a redemption price of 106.5% of the principal amount of the 2020 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 Sabine Pass LNG redeems the 2020 Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 Notes originally issued remains outstanding after the redemption.

Under the Sabine Pass LNG Indentures, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied: 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 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 Sabine Pass LNG Indentures. During the three months ended September 30, 2013 and 2012, Sabine Pass LNG made distributions of $93.0 million and $36.2 million, respectively, after satisfying all the applicable conditions in the Sabine Pass LNG Indentures. During the nine months ended September 30, 2013 and 2012, Sabine Pass LNG made distributions of $242.1 million and $182.9 million, respectively, after satisfying all the applicable conditions in the Sabine Pass LNG Indentures.

Sabine Pass Liquefaction Senior Notes

In February 2013 and April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $2.0 billion, before premium, of the 2021 Sabine Pass Liquefaction Senior Notes. In April 2013, Sabine Pass Liquefaction also issued $1.0 billion of the 2023 Sabine Pass Liquefaction Senior Notes. Borrowings under the Sabine Pass Liquefaction Senior Notes bear interest at a fixed rate of 5.625%. Interest on the 2021 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on February 1 and August 1 of each year. Interest on the 2023 Sabine Pass Liquefaction Senior Notes is payable semi-annually in arrears on April 15 and October 15 of each year.

The terms of the 2021 Sabine Pass Liquefaction Senior Notes and the 2023 Sabine Pass Liquefaction Senior Notes are governed by a common indenture (the "Indenture"). The Indenture contains customary terms and events of default and certain covenants that, among other things, limit Sabine Pass Liquefaction's ability and the ability of Sabine Pass Liquefaction's restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of Sabine Pass Liquefaction's restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, consolidate, merge, sell or lease all or substantially all of Sabine Pass Liquefaction's assets and enter into certain LNG sales contracts. Subject to permitted liens, the Sabine Pass Liquefaction Senior Notes are secured on a pari passu first-priority basis by a security interest in all of the membership interests in Sabine Pass Liquefaction and substantially all of Sabine Pass Liquefaction's assets. Sabine Pass Liquefaction may not make any distributions until, among other requirements, substantial completion of Train 1 and Train 2 has occurred, deposits are made into debt service reserve accounts and a debt service coverage ratio for the prior 12-month period and a projected debt service coverage ratio for the upcoming 12-month period of 1.25:1.00 are satisfied.

At any time prior to November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction may redeem all or a part of the Sabine Pass Liquefaction Senior Notes, at a redemption price equal to the "make-whole" price set forth in the Indenture, plus accrued and unpaid interest, if any, to the date of redemption. Sabine Pass Liquefaction also may at any time on or after November 1, 2020, with respect to the 2021 Sabine Pass Liquefaction Senior Notes, or January 15, 2023, with respect to the 2023 Sabine Pass Liquefaction Senior Notes, redeem the Sabine Pass Liquefaction Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the Sabine Pass Liquefaction Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

In connection with the issuances of the Sabine Pass Liquefaction Senior Notes, Sabine Pass Liquefaction also entered into registration rights agreements (the "Liquefaction Registration Rights Agreements"). Under the Liquefaction Registration Rights Agreements, Sabine Pass Liquefaction has agreed to use commercially reasonable efforts to file with the SEC and cause to become effective registration statements relating to an offer to exchange the Sabine Pass Liquefaction Senior Notes for a like aggregate principal amount of SEC-registered notes with terms identical in all material respects to the 2021 Sabine Pass Liquefaction Senior Notes and 2023 Sabine Pass Liquefaction Senior Notes (other than with respect to restrictions on transfer or to any increase in annual interest rate) within 360 days after February 1, 2013 for $1.5 billion of the 2021 Sabine Pass Liquefaction Senior Notes and within 295 days after April 16, 2013 for $500.0 million of the 2021 Sabine Pass Liquefaction Senior Notes and all of the 2023 Sabine Pass Liquefaction Senior Notes. Under specified circumstances, Sabine Pass Liquefaction may be required to file a shelf registration statement to cover resales of the Sabine Pass Liquefaction Senior Notes. If Sabine Pass Liquefaction fails to satisfy these obligations, Sabine Pass Liquefaction may be required to pay additional interest to holders of the Sabine Pass Liquefaction Senior Notes under certain circumstances.

2013 Liquefaction Credit Facilities

In May 2013, Sabine Pass Liquefaction closed the 2013 Liquefaction Credit Facilities aggregating $5.9 billion. The 2013 Liquefaction Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation the first four LNG Trains of the Liquefaction Project. The 2013 Liquefaction Credit Facilities will mature on the earlier of May 28, 2020 or the second anniversary of the completion date of the first four LNG Trains of the Liquefaction Project, as defined in the 2013 Liquefaction Credit Facilities. Borrowings under the 2013 Liquefaction Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2013 Liquefaction Credit Facilities in June 2013 after meeting the required conditions precedent.

Borrowings under the 2013 Liquefaction Credit Facilities bear interest at a variable rate per annum equal to, at Sabine Pass Liquefaction's election, the London Interbank Offered Rate ("LIBOR") or the base rate, plus the applicable margin. The applicable margins for LIBOR loans prior to, and after, the completion of Train 4 range from 2.3% to 3.0% and 2.3% to 3.25%, respectively, depending on the applicable 2013 Liquefaction Credit Facility. Interest on LIBOR loans is due and payable at the end of each LIBOR period. The 2013 Liquefaction Credit Facilities required Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $144.0 million and provide for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment. Annual administrative fees must also be paid to the agent and the trustee. The principal of loans made under the 2013 Liquefaction Credit Facilities must be repaid in quarterly installments, commencing upon the earlier of the last day of the first calendar quarter ending at least three months following the completion of Train 4 of the Liquefaction Project and September 30, 2018. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2013 Liquefaction Credit Facilities.

Under the terms and conditions of the 2013 Liquefaction Credit Facilities, all cash held by Sabine Pass Liquefaction is controlled by a collateral agent. These funds can only be released by the collateral agent upon satisfaction of certain terms and conditions related to the use of proceeds, and are classified as restricted on our Consolidated Balance Sheets.

The 2013 Liquefaction Credit Facilities contain conditions precedent for the second borrowing and any subsequent borrowings, as well as customary affirmative and negative covenants. The obligations of Sabine Pass Liquefaction under the 2013 Liquefaction Credit Facilities are secured by substantially all of the assets of Sabine Pass Liquefaction as well as all of the membership interests in Sabine Pass Liquefaction on a pari passu basis with the Sabine Pass Liquefaction Senior Notes.

Under the terms of the 2013 Liquefaction Credit Facilities, Sabine Pass Liquefaction is required to hedge not less than 75% 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. See Note 9— "Financial Instruments".

2012 Liquefaction Credit Facility

In July 2012, Sabine Pass Liquefaction entered into the $3.6 billion 2012 Liquefaction Credit Facility with a syndicate of lenders. The 2012 Liquefaction Credit Facility was intended to be used to fund a portion of the costs of developing, constructing and placing into operation Train 1 and Train 2 of the Liquefaction Project. In May 2013, the 2012 Liquefaction Credit Facility was amended and restated with the 2013 Liquefaction Credit Facilities and $100.0 million of outstanding borrowings under the 2012 Liquefaction Credit Facility were repaid in full.

The 2012 Liquefaction Credit Facility had a maturity date of the earlier of July 31, 2019 or the second anniversary of the completion date of Train 1 and Train 2 of the Liquefaction Project, as defined in the 2012 Liquefaction Credit Facility. Borrowings under the 2012 Liquefaction Credit Facility could have been refinanced, in whole or in part, at any time without premium or penalty, except for interest rate hedging and interest rate breakage costs. Sabine Pass Liquefaction made a $100.0 million borrowing under the 2012 Liquefaction Credit Facility in August 2012 after meeting the required conditions precedent.

Borrowings under the 2012 Liquefaction Credit Facility bore interest at a variable rate equal to, at Sabine Pass Liquefaction's election, LIBOR or the base rate, plus the applicable margin. The applicable margin for LIBOR loans was 3.50% during construction and 3.75% during operations. Interest on LIBOR loans was due and payable at the end of each LIBOR period. The 2012 Liquefaction Credit Facility required Sabine Pass Liquefaction to pay certain up-front fees to the agents and lenders in the aggregate amount of approximately $178 million and provided for a commitment fee calculated at a rate per annum equal to 40% of the applicable margin for LIBOR loans, multiplied by the average daily amount of the undrawn commitment. Annual administrative fees were also required to be paid to the agent and the trustee. The principal of loans made under the 2012 Liquefaction Credit Facility had to be repaid in quarterly installments, commencing with the last day of the first calendar quarter ending at least three months following the completion of Train 1 and Train 2 of the Liquefaction Project. Scheduled repayments were based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2012 Liquefaction Credit Facility.

Under the terms and conditions of the 2012 Liquefaction Credit Facility, all cash held by Sabine Pass Liquefaction was controlled by the collateral agent. These funds could only be released by the collateral agent upon satisfaction of certain terms and conditions related to the use of proceeds, and the cash balance of $100.0 million held in these accounts as of December 31, 2012 was classified as restricted on our Consolidated Balance Sheets.

The 2012 Liquefaction Credit Facility contained conditions precedent for the second borrowing and any subsequent borrowings, as well as customary affirmative and negative covenants. The obligations of Sabine Pass Liquefaction under the 2012 Liquefaction Credit Facility were secured by substantially all of the assets of Sabine Pass Liquefaction as well as all of the membership interests in Sabine Pass Liquefaction, and a security interest in Cheniere Partners' rights under its Unit Purchase Agreement with Blackstone CQP Holdco LP dated May 14, 2012 on a pari passu basis with the Sabine Pass Liquefaction Senior Notes.

Under the terms of the 2012 Liquefaction Credit Facility, Sabine Pass Liquefaction was required to hedge not less than 75% 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. See Note 9—"Financial Instruments".

In February 2013, Sabine Pass Liquefaction issued the 2021 Sabine Pass Liquefaction Senior Notes to refinance a portion of the 2012 Liquefaction Credit Facility, and a portion of available commitments pursuant to the 2012 Liquefaction Credit Facility was suspended. In April 2013, Sabine Pass Liquefaction issued an aggregate principal amount of $500.0 million of additional 2021 Sabine Pass Liquefaction Senior Notes and $1.0 billion of 2023 Sabine Pass Liquefaction Senior Notes, and as a result, approximately $1.4 billion of commitments under the 2012 Liquefaction Credit Facility were terminated. The termination of these commitments in April 2013 and the amendment and restatement of the 2012 Liquefaction Credit Facility with the 2013 Liquefaction Credit Facilities in May 2013 resulted in a write-off of debt issuance costs associated with the 2012 Liquefaction Credit Facility of zero and $80.5 million in the three and nine months ended September 30, 2013, respectively.

CTPL Credit Facility

In May 2013, CTPL entered into the CTPL Credit Facility, which will be used to fund modifications to the Creole Trail Pipeline and for general business purposes. CTPL incurred $10.0 million of direct lender fees that were recorded as a debt discount. The CTPL Credit Facility matures in 2017 when the full amount of the outstanding principal obligations must be repaid. CTPL's loans may be repaid, in whole or in part, at any time without premium or penalty. As of September 30, 2013, CTPL had borrowed the full amount of $400.0 million available under the CTPL Credit Facility.

Borrowings under the CTPL Credit Facility bear 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.

Under the terms and conditions of the CTPL 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. CTPL is also required to pay annual fees to the administrative and collateral agents.

The CTPL Credit Facility contains customary affirmative and negative covenants. The obligations of CTPL under the CTPL Credit Facility are secured by a first priority lien on substantially all of the personal property of CTPL and all of the general partner and limited partner interests in CTPL.

Cheniere Partners has guaranteed (i) the obligations of CTPL under the CTPL Credit Facility if the maturity of the CTPL loans is accelerated following the termination by Sabine Pass Liquefaction of a transportation precedent agreement in limited circumstances and (ii) the obligations of Cheniere Energy Investments, LLC ("Cheniere Investments"), Cheniere Partners' wholly owned subsidiary, in connection with its obligations under an equity contribution agreement (a) to pay operating expenses of CTPL until CTPL receives revenues under a service agreement with Sabine Pass Liquefaction and (b) to fund interest payments on the CTPL loans after the funds in an interest reserve account have been exhausted.

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Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2013

Property, Plant and Equipment [Abstract]

Schedule of capitalized terminal, natural gas pipeline, LNG site and related costs

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

	September 30,			December 31,
	2013			2012
LNG terminal costs
LNG terminal	$	2,233,748		$	2,233,595
LNG terminal construction-in-process	3,735,876			1,269,798
LNG site and related costs, net	5,766			5,398
Accumulated depreciation	(278,071		)	(235,275		)
Total LNG terminal costs, net	5,697,319			3,273,516
Fixed assets and other
Computer and office equipment	7,808			7,014
Furniture and fixtures	4,167			4,057
Computer software	13,125			13,012
Leasehold improvements	7,226			6,989
Other	7,552			6,844
Accumulated depreciation	(31,630		)	(29,127		)
Total fixed assets, net	8,248			8,789
Property, plant and equipment, net	$	5,705,567		$	3,282,305

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Business Segment Information

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Business Segment Information

BUSINESS SEGMENT INFORMATION

We have two operating business segments: LNG terminal business and LNG and natural gas marketing business. We determine our reporting units by identifying each unit 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 makers for purposes of resource allocation and performance assessment, and had discrete financial information.

Our LNG terminal business segment consists of the operational Sabine Pass LNG terminal, approximately 57.9% owned (at September 30, 2013), located on the Sabine Pass deep water shipping channel less than four miles from the Gulf Coast, and two other LNG terminals that are in various stages of development at the following locations: Corpus Christi LNG, 100% owned, near Corpus Christi, Texas; and Creole Trail LNG, 100% owned, at the mouth of the Calcasieu Channel in central Cameron Parish, Louisiana. The Sabine Pass LNG terminal includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with capacity of up to 265,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d, and pipeline facilities interconnecting the Sabine Pass LNG terminal with a number of large interstate pipelines. Cheniere Partners is currently developing the Liquefaction Project at the Sabine Pass LNG terminal adjacent to the existing regasification facilities. During the fourth quarter of 2012, we merged our natural gas pipeline business segment into our LNG terminal business segment because we were no longer developing or making resource allocation decisions on other pipeline projects not primarily related to our LNG terminals. We have adjusted the corresponding items of segment information for 2012 to reflect this change.

Our LNG and natural gas marketing business segment consists of Cheniere Marketing marketing LNG and natural gas on its own behalf and on behalf of Cheniere Partners in an effort to utilize the receiving capacity held at the Sabine Pass LNG terminal during construction of the Liquefaction Project.

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

	Segments
	LNG Terminal			LNG & Natural Gas Marketing				Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended September 30, 2013
Revenues (2)	$	67,558		$	16,470			$	(16,318	)	$	67,710
Intersegment revenues (losses) (3) (4)	820			15,880				(16,700		)	—
Depreciation, depletion and amortization	14,581			251				414			15,246
Non-cash compensation	3,148			4,594				20,197			27,939
Income (loss) from operations	(49,600		)	2,919				805			(45,876		)
Interest expense, net	(55,378		)	—				2,850			(52,528		)
Income (loss) before income taxes and non-controlling interest	(127,202		)	2,515				4,013			(120,674		)
Goodwill	76,819			—				—			76,819
Total assets	7,719,551			63,756				342,546			8,125,853
Expenditures for additions to long-lived assets	852,847			61				389			853,297
As of or for the Three Months Ended September 30, 2012
Revenues (2)	$	69,868		$	2,661		—	$	(6,531	)	$	65,998
Intersegment revenues (losses) (3) (4)	3,929			2,953				(6,882		)	—
Depreciation, depletion and amortization	14,566			256				411			15,233
Non-cash compensation	6,505			9,256				36,104			51,865
Loss from operations	(16,446		)	(16,462		)		(21,609		)	(54,517		)
Interest expense, net	(55,333		)	12				9,817			(45,504		)
Income (loss) before income taxes and non-controlling interest	(71,335		)	418,655				(459,135		)	(111,815		)
Goodwill	76,819			—				—			76,819
Total assets	4,136,574			42,308				204,843			4,383,725
Expenditures for additions to long-lived assets	883,798			(6		)		696			884,488
For the Nine Months Ended September 30, 2013
Revenues (2)	$	201,408		$	27,627			$	(28,242	)	$	200,793
Intersegment revenues (losses) (3) (4)	2,184			27,186				(29,370		)	—
Depreciation, depletion and amortization	43,405			751				1,377			45,533
Non-cash compensation	22,477			36,234				152,635			211,346
Loss from operations	(103,655		)	(39,543		)		(106,410		)	(249,608		)
Interest expense, net	(156,644		)	—				21,838			(134,806		)
Income (loss) before income taxes and non-controlling interest	128,441			(40,092		)		(496,613		)	(408,264		)
Expenditures for additions to long-lived assets	2,467,210			57				1,293			2,468,560
For the Nine Months Ended September 30, 2012
Revenues (2)	$	206,249		$	977			$	(8,427	)	$	198,799
Intersegment revenues (losses) (3) (4)	6,973			2,618				(9,591		)	—
Depreciation, depletion and amortization	43,810			1,815				1,376			47,001
Non-cash compensation	6,964			10,657				38,492			56,113
Income (loss) from operations	7,237			(31,788		)		(35,366		)	(59,917		)
Interest expense, net	(165,251		)	12				5,520			(159,719		)
Loss before income taxes and non-controlling interest	(158,016		)	403,369				(491,875		)	(246,522		)
Expenditures for additions to long-lived assets	931,542			1,659				1,192			934,393

(1) Includes corporate activities, oil and gas exploration, development and exploitation activities and certain intercompany eliminations. Our oil and gas exploration, development and exploitation operating 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 and international revenue allocations using a cost plus transfer pricing methodology.

(3) Intersegment revenues related to our LNG terminal business segment are primarily from tug revenues from Cheniere Marketing and the receipt of 80% of gross margins earned by Cheniere Marketing in an effort to utilize the reserved capacity at the Sabine Pass LNG terminal of Cheniere Investments under its terminal use rights assignment and agreement ("TURA") pursuant to which Cheniere Investments has the right to use Sabine Pass Liquefaction's reserved capacity at the Sabine Pass LNG terminal under Sabine Pass Liquefaction's TUA in the three and nine months ended September 30, 2013 and 2012. These LNG terminal business segment intersegment revenues are eliminated with intersegment expenses in our Consolidated Statements of Operations.

(4) Intersegment revenues (losses) related to our LNG and natural gas marketing business segment are primarily from Cheniere Marketing's tug costs and the payment of 80% of gross margins earned by Cheniere Marketing in an effort to utilize the reserved capacity at the Sabine Pass LNG terminal of Cheniere Investments under its TURA in the three and nine months ended September 30, 2013 and 2012. These LNG and natural gas marketing business segment intersegment costs are eliminated with intersegment revenues in our Consolidated Statements of Operations.

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Document and Entity Information Document	9 Months Ended
	Sep. 30, 2013	Oct. 16, 2013
Entity Information [Line Items]
Entity Registrant Name	CHENIERE ENERGY INC
Entity Central Index Key	0000003570
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		238,896,010
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes

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Supplemental Cash Flow Information (Notes)

9 Months Ended

Sep. 30, 2013

Supplemental Cash Flow Information [Abstract]

Supplemental Cash Flow Information and Disclosure of Non-cash Transactions

SUPPLEMENTAL CASH FLOW INFORMATION AND DISCLOSURES OF NON-CASH TRANSACTIONS

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

	Nine Months Ended September 30,
	2013		2012
Cash paid during the year for interest, net of amounts capitalized and deferred	$	56,428	$	117,190
LNG terminal costs funded with accounts payable and accrued liabilities	80,557		52,830