10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended March 31, 2007

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 as specified in its charter)

Delaware

(State or other jurisdiction of incorporation or organization)

95-4352386

(I.R.S. Employer Identification No.)

700 Milam Street, Suite 800

Houston, Texas

(Address of principal executive offices)

77002

(Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

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

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

Large accelerated filer  x                Accelerated filer  ¨                Non-accelerated filer  ¨

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

As of April 30, 2007, there were 56,266,353 shares of Cheniere Energy, Inc. Common Stock, $0.003 par value, issued and outstanding.

CHENIERE ENERGY, INC.

INDEX TO FORM 10-Q

		Page
Part I. FINANCIAL INFORMATION
Item 1.	Consolidated Financial Statements
	Consolidated Balance Sheets	1
	Consolidated Statements of Operations	2
	Consolidated Statement of Stockholders’ Equity	3
	Consolidated Statements of Cash Flows	4
	Notes to Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	21
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	37
Item 4.	Disclosure Controls and Procedures	37
Part II. OTHER INFORMATION
Item 1.	Legal Proceedings	38
Item 5.	Other Information	38
Item 6.	Exhibits	40

i

PART I. FINANCIAL INFORMATION

Item 1. Consolidated Financial Statements

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands, except share data)

	March 31, 2007			December 31, 2006
	(unaudited)
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	583,620		$	462,963
Restricted cash and cash equivalents		218,145			176,827
Interest receivable		6,396			6,642
Accounts receivable		8,146			1,299
Derivative assets		46			—
Prepaid expenses and other		14,990			2,242
TOTAL CURRENT ASSETS		831,343			649,973
NON-CURRENT RESTRICTED CASH AND CASH EQUIVALENTS		900,458			1,071,722
NON-CURRENT RESTRICTED TREASURY SECURITIES		86,304			—
PROPERTY, PLANT AND EQUIPMENT, NET		957,177			748,818
DEBT ISSUANCE COSTS, NET		39,877			41,545
GOODWILL		76,844			76,844
INTANGIBLE ASSETS		4,331			4,331
ADVANCES UNDER LONG-TERM CONTRACTS		14,022			7,101
OTHER		2,005			4,154
TOTAL ASSETS	$	2,912,361		$	2,604,488
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES
Accounts payable	$	13,256		$	3,659
Accrued liabilities		118,920			58,280
Derivative liabilities		1,406			—
TOTAL CURRENT LIABILITIES		133,582			61,939
LONG-TERM DEBT		2,357,000			2,357,000
DEFERRED REVENUE		41,000			41,000
OTHER NON-CURRENT LIABILITIES		1,518			1,302
MINORITY INTEREST		262,887			—
COMMITMENTS AND CONTINGENCIES		—			—
STOCKHOLDERS’ EQUITY
Preferred stock, $0.001 par value, 5,000,000 shares authorized, none issued. Common stock, $0.003 par value		—			—
Authorized: 120,000,000 shares at both March 31, 2007 and December 31, 2006
Issued and outstanding: 56,113,685 shares at March 31, 2007 and 55,212,771 shares at December 31, 2006		168			166
Treasury stock, 2,232 shares, at cost		(62	)		—
Additional paid-in-capital		398,004			390,256
Accumulated deficit		(281,697	)		(247,141	)
Accumulated other comprehensive loss		(39	)		(34	)
Total stockholders’ equity		116,374			143,247
Total liabilities and stockholders’ equity	$	2,912,361		$	2,604,488

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

1

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

(unaudited)

	Three Months Ended March 31,
	2007			2006
Revenues
Oil and gas sales	$	832		$	422
Marketing and trading loss		(2,088	)		—
Total revenues		(1,256	)		422
Operating costs and expenses
LNG receiving terminal and pipeline development expenses		5,754			8,313
Exploration costs		359			838
Oil and gas production costs		67			51
Depreciation, depletion and amortization		1,075			606
General and administrative expenses		21,261			13,181
Total operating costs and expenses		28,516			22,989
Loss from operations		(29,772	)		(22,567	)
Derivative gain		—			761
Interest expense		(26,426	)		(11,138	)
Interest income		21,582			9,544
Other income		—			176
Loss before income taxes and minority interest		(34,616	)		(23,224	)
Income tax benefit		—			7,413
Loss before minority interest		(34,616	)		(15,811	)
Minority interest		60			—
Net loss	$	(34,556	)	$	(15,811	)
Net loss per common share—basic and diluted	$	(0.63	)	$	(0.29	)
Weighted average number of common shares outstanding—basic and diluted		54,891			54,217

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

2

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF STOCKHOLDERS’ EQUITY

(in thousands)

(unaudited)

	Common Stock				Treasury Stock					Additional Paid-In Capital			Accumulated Deficit			Accumulated Other Comprehensive Income (loss)			Total Stockholders’ Equity
	Shares		Amount		Shares		Amount
Balance—December 31, 2006	55,213		$	166	—		$	—		$	390,256		$	(247,141	)	$	(34	)	$	143,247
Issuances of stock	258			—	—			—			760			—			—			760
Issuances of restricted stock	648			2	—			—			(2	)		—			—			—
Forfeitures of restricted stock	(3	)		—	—			—			—			—			—			—
Stock-based compensation	—			—	—			—			6,990						—			6,990
Treasury stock acquired	—			—	(2	)		(62	)		—			—			—			(62	)
Comprehensive loss:
Foreign currency translation	—			—	—			—			—			—			(5	)		(5	)
Net loss	—			—	—			—			—			(34,556	)		—			(34,556	)
Balance—March 31, 2007	56,116		$	168	(2	)	$	(62	)	$	398,004		$	(281,697	)	$	(39	)	$	116,374

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

3

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Three Months Ended March 31,
	2007			2006
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(34,556	)	$	(15,811	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization		1,075			606
Impairment of unproved properties		334			323
Dry hole expense		8			240
Amortization of debt issuance costs		1,295			918
Non-cash compensation		6,610			5,600
Restricted interest income on restricted cash and cash equivalents		(14,845	)		—
Deferred tax benefit		—			(7,413	)
Non-cash derivative gain		—			(722	)
Minority interest		(60	)		—
Other		(10	)		184
Changes in operating assets and liabilities
Interest receivable		(2	)		—
Other accounts receivable		(7,257	)		281
Prepaid expenses		(12,763	)		(2,014	)
Accounts payable and accrued liabilities		31,715			(2,670	)
NET CASH USED IN OPERATING ACTIVITIES		(28,456	)		(20,478	)
CASH FLOWS FROM INVESTING ACTIVITIES:
LNG terminal and pipeline construction-in-progress		(160,732	)		(73,807	)
Use of restricted cash and cash equivalents		157,183			17,203
Investments in restricted treasury securities		(98,442	)		—
Purchases of fixed assets		(6,234	)		(1,655	)
Additions of oil and gas property		(5	)		(1,954	)
Advances under long-term contracts		(6,920	)		—
Sale of interest in oil and gas prospects		—			448
Other		1,252			(5	)
NET CASH USED IN INVESTING ACTIVITIES		(113,898	)		(59,770	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuances of common units in partnership		164,505			—
Proceeds from issuance of common units to minority owners in partnership		98,442			—
Repayment of Term Loan		—			(1,500	)
Borrowings under Sabine Pass credit facility		—			70,000
Debt issuance costs		(634	)		(2,978	)
Sale of common stock		760			1,164
Purchase of treasury shares		(62	)		(932	)
NET CASH PROVIDED BY FINANCING ACTIVITIES		263,011			65,754
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		120,657			(14,494	)
CASH AND CASH EQUIVALENTS—BEGINNING OF PERIOD		462,963			692,592
CASH AND CASH EQUIVALENTS—END OF PERIOD	$	583,620		$	678,098

The accompanying notes are an integral part of these financial statements

4

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—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 the instructions to Form 10-Q and 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. As used herein, the terms “Cheniere,” “we,” “our” and “us” refer to Cheniere Energy, Inc. and its wholly-owned or controlled subsidiaries.

Certain reclassifications have been made to conform prior period information to the current presentation including a $179.0 million reclassification between current Restricted Cash and Cash Equivalents and Non-Current Restricted Cash and Cash Equivalents on our December 31, 2006 Consolidated Balance Sheet. The reclassification had no effect on our overall consolidated financial position, results of operations or cash flows.

Interim results are not necessarily indicative of results to be expected for the full fiscal year ending December 31, 2007.

For further information, refer to the consolidated financial statements and footnotes included in our annual report on Form 10-K for the year ended December 31, 2006.

New Accounting Pronouncements

In July 2006, the Financial Accounting Standards Board (“FASB”) issued FASB Interpretation No. 48, Accounting for Uncertainty in Income Taxes—An Interpretation of FASB Statement No. 109 (“FIN No. 48”). FIN No. 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 109, Accounting for Income Taxes. It prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This new standard also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. The provisions of FIN No. 48 are to be applied to all tax positions upon initial adoption of this standard. Only tax positions that meet the more likely-than-not recognition threshold at the effective date may be recognized or continue to be recognized upon adoption of FIN No. 48. The cumulative effect of applying the provisions of FIN No. 48 should be reported as an adjustment to the opening balance of retained earnings (or other appropriate components of equity or net assets in the statement of financial position) for that fiscal year. We adopted FIN No. 48 in the first quarter of 2007. The adoption of FIN No. 48 had no material impact on our financial position, results of operations or cash flows.

In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115. This statement permits entities to choose to measure many financial instruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. This statement is expected to expand the use of fair value measurement, which is consistent with the FASB’s long-term measurement objectives for accounting for financial instruments. This statement is effective as of the beginning of an entity’s first fiscal year that begins after November 15, 2007, although earlier adoption is permitted. Management has not determined the effect that adopting this statement would have on our financial condition or results of operations.

5

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 2—Initial Public Offering of Cheniere Energy Partners, L.P. and Minority Interest

On March 26, 2007, Cheniere Energy Partners, L.P. (“Cheniere Partners”) and Cheniere LNG Holdings, LLC (“Holdings”), our wholly-owned subsidiary, completed a public offering of 13,500,000 Cheniere Partners common units (the “Offering”). Cheniere Partners is a Delaware limited partnership formed by us to develop, own and operate the Sabine Pass liquefied natural gas (“LNG”) receiving terminal. Upon the closing of the Offering, the following transactions occurred:

• Holdings contributed its ownership interests in the entities that directly or indirectly own the Sabine Pass LNG receiving terminal to Cheniere Energy Investments, LLC, a wholly-owned subsidiary of Cheniere Partners;

• Cheniere Partners issued 21,362,193 common units, 135,383,831 subordinated units, 3,302,045 general partner units (representing a 2% general partner interest) and certain general partner incentive distribution rights to wholly-owned subsidiaries of Cheniere;

• Cheniere Partners issued 5,054,164 common units to the public and received net proceeds of $98.4 million; and

• Holdings sold 8,445,836 common units to the public and received net proceeds of $164.5 million, after which Cheniere and the public owned 89.8% and 8.2% limited partner interests in Cheniere Partners, respectively. Holdings also granted the underwriters an option to purchase an additional 2,025,000 of its Cheniere Partners’ common units to cover over-allotments in connection with the Offering (see Note 17—Subsequent Events).

Cheniere Partners used all of the net proceeds of $98.4 million it received to purchase U.S. treasury securities to fund a distribution reserve for payment of initial quarterly distributions of $0.425 per common unit as well as related quarterly distributions to its general partner, through June 30, 2009.

The net proceeds of $164.5 million from the sale of the common units by Holdings and the net proceeds of $39.4 million that it received from the subsequent exercise of the underwriters’ option to purchase additional common units from us (see Note 17—Subsequent Events) are not assets of Cheniere Partners and therefore are unrestricted as to our use.

As of March 31, 2007, our combined general partner and limited partner ownership interests in Cheniere Partners was reduced to approximately 91.8%, before exercise of the underwriters’ over-allotment option. As of such date, we held 135,383,831 subordinated units, 12,916,357 common units and 3,302,045 general partner units of Cheniere Partners. During the subordination period, the subordinated units will not be entitled to receive any distributions until the common units have received the initial quarterly distributions plus any arrearages on the initial quarterly distribution from prior quarters. Our subordinated units do not accrue arrearages. The subordination period generally will end if:

• Cheniere Partners has earned and paid at least $0.425 on each outstanding common unit, subordinated unit and general partner unit for each of the three consecutive, non-overlapping four-quarter periods ending on or after June 30, 2010; or

• if Cheniere Partners has earned and paid at least $0.638 (150% of the initial quarterly distribution) on each outstanding common unit, subordinated unit and general partner unit for any four consecutive quarters ending on or after June 30, 2008.

The portion of the common units held by the public is presented as a minority interest on our Consolidated Balance Sheets. Losses attributable to the minority interest are presented separately on our Consolidated Statements of Operations based upon the minority interest’s share of Cheniere Partners’ losses calculated in accordance with Cheniere Partners’ partnership agreement.

6

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

The following table sets forth the components of our minority interest balance attributable to third-party investors’ interest in Cheniere Partners as a result of the Offering (in thousands):

Net proceeds from Cheniere Partners’ issuance of common units(1)	$	98,442
Net proceeds from Holdings’ sale of Cheniere Partners common units(2)		164,505
Minority interest share of loss of Cheniere Partners		(60	)
Minority interest at March 31, 2007	$	262,887

(1) Through the Offering, Cheniere Partners received $98.4 million in proceeds net of offering costs from the issuance of its common units to the public. Securities and Exchange Commission (“SEC”) Staff Accounting Bulletin (“SAB”) No. 51, Accounting for Sales of Stock by a Subsidiary, provides guidance on accounting by the parent for issuances of a subsidiary’s common equity to unaffiliated parties. Under SAB No. 51, a company may elect an accounting policy of recording a gain or loss on the sale of common equity of a subsidiary equal to the amount of proceeds received in excess of the carrying value of the parent’s investment. Upon the conversion of all of our subordinated units in Cheniere Partners to common units, we will evaluate whether to recognize a gain through earnings at that time.

(2) In conjunction with the Offering, Holdings sold a portion of the Cheniere Partners common units held by it to the public, realizing proceeds net of offering costs of $164.5 million. Due to the existence of our ownership in equity in the partnership having subordinated distribution rights, we have recorded those proceeds as a minority interest. Upon the conversion of all of our subordinated units in Cheniere Partners to common units, we will evaluate whether to recognize a gain through earnings at that time.

NOTE 3—Restricted Cash, Cash Equivalents and Treasury Securities

In August 2006, Cheniere Creole Trail Pipeline, L.P. (“CCTP”), our wholly-owned subsidiary, entered into a purchase order with ILVA S.p.A (“ILVA”) for the purchase of pipe at an aggregate cost of approximately $175.7 million. Associated with this purchase order, CCTP delivered a standby letter of credit to ILVA in the amount of $87.9 million to secure CCTP’s obligations under the purchase order. This letter of credit required a deposit of $87.9 million with the issuer of the letter of credit, which was recorded as Non-Current Restricted Cash and Cash Equivalents on our Consolidated Balance Sheet at December 31, 2006. Once payments by CCTP under the purchase order exceed the value of the letter of credit, ILVA will submit a notice of reduction to the issuing bank to reduce the amount of the letter of credit by 100% of any subsequent payments by CCTP. The Non-Current Restricted Cash and Cash Equivalents cash collateral account on deposit with the issuing bank will be reduced by such amount. In January 2007, CCTP amended the ILVA purchase order to terminate for convenience 610,560 of the 952,700 feet of pipe originally required under the purchase order. The cancellation fee of $0.5 million under the terms of the original purchase order was waived. The amendment called for a decrease to the face amount of the purchase order and the related letter of credit and cash collateral deposit from $87.9 million to $4.1 million. As a result of the amendment, we were able to release the restriction on the cash associated with the reduction of the purchase order.

In November 2006, Sabine Pass LNG, L.P. our wholly-owned subsidiary (“Sabine Pass LNG”), consummated a private offering of an aggregate principle amount of $2 billion of Senior Secured Notes consisting of $550 million of 7 ¹/4% Senior Secured Notes due 2013 (the “2013 Notes”) and $1.5 billion of 7 ¹/2% Senior Secured Notes due 2016 (the “2016 Notes” and, collectively with the 2013 Notes, the “Sabine Pass LNG notes”) (see Note 7—Long-Term Debt). Under the terms and conditions of the Sabine Pass LNG notes, we were required to fund cash reserve accounts for approximately $335 million related to future interest payments through May 2009 and approximately $887 million to pay the remaining costs to complete the initial phase (“Phase 1”) and the first stage of the second phase (“Phase 2–Stage 1”) of the Sabine Pass LNG receiving terminal. These cash accounts are controlled by a collateral trustee, and therefore, are shown as restricted cash and cash

7

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

equivalents on our Consolidated Balance Sheet. As of March 31, 2007 and December 31, 2006, $209.6 million and $176.3 million, respectively, related to future interest payments due within one year and accrued construction costs have been classified as a current asset, and $895.1 million and $982.6 million, respectively, related to remaining construction costs and future interest payments due beyond one year have been classified as a non-current asset on our Consolidated Balance Sheet.

As discussed above in Note 2 at the closing of the Offering, we funded a distribution reserve for $98.4 million, which was invested in U.S. treasury securities. The distribution reserve, including interest earned thereon, will be used to pay quarterly distributions of $0.425 per common unit for all common units, as well as related distributions to Cheniere Partners’ general partner, through June 30, 2009. The U.S. treasury securities were acquired at a discount from their maturity values equal to an average of approximately 4.87% per year. As of March 31, 2007, we have classified $86.3 million of the U.S. treasury securities as Non-Current Restricted Treasury Securities on our Consolidated Balance Sheet as these securities have maturities greater than three months. The remaining $12.1 million invested in U.S. treasury securities are classified as Non-Current Restricted Cash and Cash Equivalents on our Consolidated Balance Sheet as of March 31, 2007, as these securities have maturities less than or equal to three months.

NOTE 4—Property, Plant and Equipment

Property, plant and equipment consists of LNG terminal and natural gas pipeline construction-in-progress expenditures, LNG site and related costs, investments in oil and gas properties and fixed assets, as follows (in thousands):

	March 31, 2007			December 31, 2006
LNG TERMINAL COSTS
LNG terminal construction-in-progress	$	802,618		$	684,008
LNG site and related costs, net		1,466			1,467
Total LNG terminal costs		804,084			685,475
NATURAL GAS PIPELINE COSTS
Pipeline construction-in-progress		125,894			45,615
Pipeline right-of-ways		5,156			2,134
Total natural gas pipeline costs		131,050			47,749
OIL AND GAS PROPERTIES, successful efforts
Proved		2,340			2,343
Unproved		445			779
Accumulated depreciation, depletion and amortization		(350	)		(263	)
Total oil and gas properties, net		2,435			2,859
FIXED ASSETS
Computer and office equipment		6,316			5,352
Furniture and fixtures		1,417			1,310
Computer software		8,465			8,043
Leasehold improvements		2,298			2,206
Projects in progress		7,932			1,724
Other		188			123
Accumulated depreciation		(7,008	)		(6,023	)
Total fixed assets, net		19,608			12,735
PROPERTY, PLANT AND EQUIPMENT, NET	$	957,177		$	748,818

8

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

LNG Terminal Costs

Once an LNG receiving terminal is placed into service, the related LNG terminal construction-in-progress costs will be depreciated using the straight-line depreciation method. We are in the process of determining the appropriate approach for grouping identifiable components with similar estimated useful lives. Estimated useful lives for components, once construction is completed, are currently estimated to range between 10 and 50 years.

In February 2005 and July 2006, Phase 1 and Phase 2—Stage l, respectively, of the Sabine Pass LNG receiving terminal project satisfied our criteria for capitalization. Accordingly, costs associated with the construction of Phase 1 and Phase 2—Stage 1 of the Sabine Pass LNG receiving terminal have been capitalized as construction-in-progress since those dates. For the three months ended March 31, 2007 and 2006, we capitalized $12.9 million and $2.1 million of interest expense related to these construction projects, respectively. In March 2006, our Corpus Christi LNG receiving terminal satisfied the criteria for capitalization. Accordingly, costs associated with the initial site work for the Corpus Christi LNG receiving terminal have been capitalized as construction-in progress since that time. For the three months ended March 31, 2007, we capitalized $0.3 million of interest expense related to this construction project.

Natural Gas Pipeline Costs

Our developing natural gas pipeline business is subject to the jurisdiction of the Federal Energy Regulatory Commission (“FERC”) in accordance with the Natural Gas Act of 1938 and the Natural Gas Policy Act of 1978, and we have determined that our pipelines to be constructed have met the criteria set forth in SFAS No. 71, Accounting for the Effects of Certain Types of Regulations. Accordingly, we began applying the provisions of SFAS No. 71 to the affected pipeline subsidiaries in the second quarter of 2006. Natural gas pipeline costs also include amounts capitalized as Allowance for Funds Used During Construction (“AFUDC”). The rates used in the calculation of AFUDC are determined in accordance with guidelines established by the FERC. AFUDC represents the cost of debt and equity funds used to finance our natural gas pipeline additions during construction. AFUDC is capitalized as a part of the cost of our natural gas pipelines. Under regulatory rate practices, we generally are permitted to recover AFUDC, and a fair return thereon, through our rate base after our natural gas pipelines are placed in service. For the three months ended March 31, 2007, we capitalized $1.3 million of AFUDC to our natural gas pipeline projects.

Fixed Assets

Our fixed assets are recorded at cost and are depreciated on a straight-line method based on estimated lives of the individual assets or groups of assets. Depreciation expense related to our property, plant and equipment totaled $1.0 million for the three months ended March 31, 2007.

NOTE 5—Investment in Limited Partnership

We account for our 30% limited partnership investment in Freeport LNG Development, L.P. (“Freeport LNG”) using the equity method of accounting. As of March 31, 2007 and December 31, 2006, we had unrecorded cumulative suspended losses of $14.7 million and $13.0 million, respectively, related to our investment in Freeport LNG, as the basis in this investment had been reduced to zero. As a result, we did not record our share of the losses of the partnership for the three months ended March 31, 2007 because we had not guaranteed any obligations and are not committed to provide any further financial support, and have not done so since December 2005.

9

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

The financial position of Freeport LNG at March 31, 2007 and December 31, 2006 and the results of Freeport LNG’s operations for the three months ended March 31, 2007 and 2006 are summarized as follows (in thousands):

	March 31, 2007			December 31, 2006
Current assets	$	259,127		$	294,847
Construction-in-progress		660,180			594,191
Fixed assets, net, and other assets		9,707			9,684
Total assets	$	929,014		$	898,722
Current liabilities	$	35,314		$	38,621
Notes payable		942,650			903,369
Deferred revenue and other deferred credits		5,645			5,666
Partners’ capital		(54,595	)		(48,934	)
Total liabilities and partners’ capital	$	929,014		$	898,722

	Three Months Ended March 31,
	2007			2006
Loss from continuing operations	$	(5,661	)	$	(10,585	)
Net loss		(5,661	)		(10,585	)
Cheniere’s 30% equity in net loss from limited partnership(1)		(1,698	)		(3,175	)

(1) As discussed above, we did not record the $1.7 million and $3.2 million losses in our Consolidated Statement of Operations for the three months ended March 31, 2007 and 2006 because our investment basis was zero.

NOTE 6—Accrued Liabilities

Accrued liabilities consisted of the following (in thousands):

	March 31, 2007		December 31, 2006
LNG terminal construction costs	$	40,060	$	16,334
Accrued interest expense and related fees		60,790		24,861
Pipeline construction costs		3,534		7,039
Debt issuance costs		—		783
Payroll		2,967		5,512
Professional and legal services		608		—
Purchased physical gas		5,760		—
Projects-in-progress		1,580		1,067
Other accrued liabilities		3,621		2,684
Accrued liabilities	$	118,920	$	58,280

10

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 7—Long-Term Debt

As of March 31, 2007 and December 31, 2006, our long-term debt consisted of the following (in thousands):

	March 31, 2007		December 31, 2006
Sabine Pass LNG notes	$	2,032,000	$	2,032,000
Convertible Senior Unsecured Notes		325,000		325,000
Total Long-Term Debt	$	2,357,000	$	2,357,000

Sabine Pass LNG Notes

In November 2006, Sabine Pass LNG, consummated a private offering of an aggregate principal amount of $2,032 million of Sabine Pass LNG notes, consisting of $550 million of the 2013 notes and $1,482 million of the 2016 notes. Sabine Pass LNG has filed a registration statement with the SEC offering to exchange the unregistered Sabine Pass LNG notes for a like amount of senior secured notes of Sabine Pass LNG which are registered under the Securities Act of 1933, as amended (“Securities Act”).

Interest on the Sabine Pass LNG notes is payable semi-annually in arrears on May 30 and November 30 of each year, beginning May 30, 2007. The Sabine Pass LNG 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.

Under the indenture governing the Sabine Pass LNG notes, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied. The indenture requires that Sabine Pass LNG apply its net operating cash flow (i) first, to fund with monthly deposits its next semiannual payment of approximately $75.5 million of interest on the Sabine Pass LNG notes, and (ii) second, to fund a one-time, permanent debt service reserve fund equal to one semiannual interest payment of approximately $75.5 million on the Sabine Pass LNG notes. Distributions from Sabine Pass LNG will be permitted only after Phase 1 target completion, as defined in the indenture governing the Sabine Pass LNG notes, or such earlier date as project revenues are received, upon satisfaction of the foregoing funding requirements, after satisfying a fixed charge coverage ratio test of 2:1 and after satisfying other conditions specified in the indenture.

Convertible Senior Unsecured Notes

In July 2005, we consummated a private offering of $325 million aggregate principal amount of Convertible Senior Unsecured Notes due August 1, 2012 to qualified institutional buyers pursuant to Rule 144A under the Securities Act. The notes bear interest at a rate of 2.25% per year. The notes are convertible at any time into our common stock under certain circumstances at an initial conversion rate of 28.2326 per $1,000 principal amount of the notes, which is equal to a conversion price of approximately $35.42 per share. We may redeem some or all of the notes on or before August 1, 2012, for cash equal to 100% of the principal plus any accrued and unpaid interest if in the previous 10 trading days the volume-weighted average price of our common stock exceeds $53.13, subject to adjustment, for at least five consecutive trading days. In the event of such a redemption, we will make an additional payment equal to the present value of all remaining scheduled interest payments through August 1, 2012, discounted at the U.S. Treasury rate plus 50 basis points. The indenture governing the notes contains customary reporting requirements.

Concurrently with the issuance of the Convertible Senior Unsecured Notes, we also entered into hedge transactions in the form of an issuer call spread (consisting of a purchase and a sale of call options on our

11

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

common stock) with an affiliate of the initial purchaser of the notes, having a term of two years and a net cost to us of $75.7 million. These hedge transactions are expected to offset potential dilution from conversion of the notes up to a market price of $70.00 per share. The net cost of the hedge transactions was recorded as a reduction to Additional Paid-in-Capital in accordance with the guidance of Emerging Issues Task Force (“EITF”) Issue 00-19, Accounting for Derivative Financial Instruments Indexed to, and Potentially Settled in, a Company’s Own Stock. Net proceeds from the offering were $239.8 million, after deducting the cost of the hedge transactions, the underwriting discount and related fees. As of March 31, 2007, no holders had elected to convert their notes.

NOTE 8—Financial Instruments

The estimated fair value of financial instruments is the amount at which the instrument could be exchanged currently between willing parties. The carrying amounts reported in the Consolidated Balance Sheets for Cash and Cash Equivalents, Accounts Receivable and Accounts Payable approximate fair value due to their short-term nature. We use available market data and valuation methodologies to estimate the fair value of debt. This disclosure is presented in accordance with SFAS No. 107, Disclosures about Fair Value of Financial Instruments, and does not impact our financial position, results of operations or cash flows.

Financial Instruments (in thousands):

	March 31, 2007				December 31, 2006
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2013 Notes (1)	$	550,000	$	554,125	$	550,000	$	547,250
2016 Notes (1)		1,482,000		1,489,410		1,482,000		1,478,295
2.25% Convertible Senior Unsecured Notes due 2012 (2)		325,000		349,577		325,000		334,750
Restricted Treasury Securities (3)		98,442		98,442		—		—

(1) The fair value of the Sabine Pass LNG notes was based on quotations obtained from broker-dealers who made markets in these and similar instruments as of March 30, 2007 and December 29, 2006 .

(2) The fair value of our Convertible Senior Unsecured Notes is based on a closing trading price on March 30, 2007 and December 29, 2006.

(3) The fair value of our Restricted Treasury Securities was based on quotations obtained from broker-dealers who made markets in these and similar instruments as of March 30, 2007. This amount includes $12.1 million classified as Non-Current Restricted Cash and Cash Equivalents on our Consolidated Balance Sheet as of March 31, 2007, as these securities have maturities less than or equal to three months.

NOTE 9—Income Taxes

From our inception, we have reported net operating losses (“NOL”) for both financial reporting purposes and for international, federal and state income tax reporting purposes. Accordingly, we are not presently a taxpayer and have not recorded a net liability for international, federal or state income taxes in any of the periods included in the accompanying financial statements. Our Consolidated Statement of Operations for the three months ended March 31, 2007 and 2006 included deferred income tax benefits of zero and $7.4 million, respectively. The deferred income tax benefit recorded for the three months ended March 31, 2006 was provided in accordance with the guidance in paragraph 140 of SFAS No. 109 and EITF Abstract, Topic D-32, which, in certain circumstances, requires items reported in pre-tax accumulated other comprehensive income (“OCI”) to be considered in the determination of the amount of tax benefit that must be reported in the Consolidated Statement of Operations when an NOL occurs. In our situation, the specific circumstance related to a pre-tax accumulated

12

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

OCI of $27.0 million recorded as of March 31, 2006 in connection with our interest rate swaps. The deferred tax benefit for the three months ended March 31, 2006 represents the portion of the change in our tax asset valuation account that was allocable to the deferred income tax on the pre-tax income items reported in accumulated OCI in our March 31 ,2006 Consolidated Statement of Stockholders’ Equity.

The income tax benefit included in our reported net loss consisted of the following (in thousands):

	Three Months Ended March 31,
	2007		2006
Current income tax expense	$	—	$	—
Deferred income tax benefit		—		7,413
	$	—	$	7,413

A substantial portion of the Sabine Pass LNG receiving terminal qualifies for the 50% bonus depreciation allowance enacted by the Gulf Opportunity Zone Act of 2005. These accelerated deductions are based on a full year estimate of the Sabine Pass LNG receiving terminal qualifying additions that will be ready to be placed in service during the remainder of 2007. The accelerated tax depreciation deduction offsets a substantial portion of the first quarter tax gain resulting from the Offering.

In May 2006, the State of Texas enacted a new business tax that is imposed on gross revenues to replace the State’s current franchise tax regime. The new legislation’s effective date is January 1, 2008, which means that our first Texas margins tax (“TMT”) return will not become due until May 15, 2008 and will be based on our 2007 operations. Although the TMT is imposed on an entity’s gross revenues rather than on its net income, certain aspects of the tax make it similar to an income tax. In accordance with the guidance provided in SFAS No. 109, we have properly determined the impact of the newly-enacted legislation in the determination of our reported state current and deferred income tax liability.

New Accounting Pronouncement

In July 2006, the FASB issued FASB Interpretation (“FIN”) No. 48, Accounting for Uncertainty in Income Taxes—An Interpretation of FASB Statement No. 109. FIN No. 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with SFAS No. 109, Accounting for Income Taxes. It prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This new standard also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition rules.

The provisions of FIN No. 48 have been applied to all of our material tax positions taken through the date of adoption and during the interim quarterly period ended March 31, 2007. We have determined that all of our material tax positions taken in our income tax returns and the positions we expect to take in our future income tax filings meet the more likely-than-not recognition threshold prescribed by FIN No. 48. In addition, we have also determined that, based on our judgment, none of these tax positions meet the definition of “uncertain tax positions” that are subject to the non-recognition criteria set forth in the new pronouncement.

Our federal consolidated income tax returns have not been audited by the Internal Revenue Service; we have not been notified of any pending federal, state or international income tax audits, and we are not aware of any

13

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

income tax controversies that are likely to occur with any taxing authority. We have not entered into any agreements with any taxing authorities to extend the period of time in which they may assert or assess additional income tax, penalties or interest. However, because we are presently in an NOL carryover position and have been since our inception, under the applicable Internal Revenue Service guidelines, in the event of an audit, our available federal NOL carryover amount is subject to adjustment until the normal three year federal statute of limitations closes for the year in which the NOL is fully utilized. The Texas Comptroller’s office recently completed an audit of Cheniere’s Texas franchise tax returns for the three year period ended December 31, 2004; the Louisiana Department of Revenue recently completed an income and franchise audit of Cheniere and one of our wholly-owned affiliates for the two year period ended December 31, 2003. We expect that all of our significant operating affiliates will be audited by the States of Texas and Louisiana for annual tax reporting periods ended on or before December 31, 2004. To date, all of the state-level income tax audits have been settled favorably and without changes. None of our foreign affiliates have been audited by any foreign taxing authorities and none have been notified of any pending tax audits.

As discussed above, we have not previously recorded a liability for international, federal or state income taxes, and therefore, we have not been subject to any penalties or interest expense related to any income tax liabilities. In future reporting periods, if any interest or penalties are imposed in connection with an income tax liability, we expect to include both of these items in the our income tax provision.

As set forth in SFAS No. 109, we have established a tax valuation allowance for the tax benefits related to our NOL carryover and our other deferred tax assets due to the uncertainty of realizing the tax benefits. If, as a result of a change in facts, any of our previously recognized tax benefits are required to be de-recognized in a future reporting period, the resulting decrease in tax benefits will be taken into account before the amount of our tax valuation allowance is established. We do not believe that it is reasonably possible that the amount of our unrecognized tax benefits will change significantly within the next twelve months. To date, the adoption of FIN No. 48 has had no impact on our financial position, results of operations or cash flows.

NOTE 10—Net Income (Loss) Per Share

Basic net income (loss) per share is computed by dividing the net income (loss) by the weighted average number of shares of common stock outstanding for the period. The computation of diluted net income (loss) per share reflects the potential dilution that could occur if securities or other contracts to issue common stock that are dilutive to net income were exercised or converted into common stock or resulted in the issuance of common stock that would then share in our earnings.

The following table reconciles basic and diluted weighted average common shares outstanding for the three months ended March 31, 2007 and 2006 (in thousands except for loss per share):

	Three Months Ended March 31,
	2007			2006
Weighted average common shares outstanding:
Basic		54,891			54,217
Dilutive common stock options		—			—
Dilutive Convertible Senior Unsecured Notes		—			—
Diluted		54,891			54,217
Basic loss per share	$	(0.63	)	$	(0.29	)
Diluted loss per share	$	(0.63	)	$	(0.29	)

14

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 11—Other Comprehensive Income (Loss)

The following table is a reconciliation of our net loss to our comprehensive loss for the three months ended March 31, 2007 and 2006 (in thousands):

	Three Months Ended March 31,
	2007			2006
Net loss	$	(34,556	)	$	(15,811	)
Other comprehensive income (loss) items:
Cash flow hedges, net of income tax		—			13,768
Foreign currency translation		(5	)		—
Comprehensive loss	$	(34,561	)	$	(2,043	)

NOTE 12—Related Party Transactions

From time to time, officers and employees may charter aircraft for company business travel. We entered into a letter agreement, or charter letter, with an unrelated third-party entity, Western Airways, Inc. (“Western”), that specified the terms under which it would provide for charter of a Challenger 600 aircraft. One of the Challenger 600 aircraft that could be provided by Western for such services was owned by Bramblebush, L.L.C. (the “LLC”). The LLC is owned and/or controlled by our Chairman and Chief Executive Officer, Charif Souki. Our Code of Business Conduct and Ethics prohibits potential conflicts of interest. Upon the recommendation of our Audit Committee, which determined that the terms of the charter letter were fair and in our best interest, our Board of Directors unanimously approved the terms of the charter letter in May 2005 and granted an exception under our Code of Business Conduct and Ethics in order to permit us to charter the Challenger 600 aircraft. For the three months ended March 31, 2006, we incurred expenses of $111,000 related to the charter of the Challenger 600 aircraft owned by the LLC. For the three months ended March 31, 2007, there were no expenses incurred related to such aircraft.

NOTE 13—Commitments and Contingencies

Amended Pipe Purchase Order

In January 2007, CCTP amended the ILVA purchase order to terminate for convenience 610,560 of the 952,700 feet of pipe originally required under the purchase order, as amended. The cancellation fee of $0.5 million under the terms of the original purchase order was waived. The amendment calls for a decrease in the face amount of the purchase order and the related letter of credit and cash collateral deposit from $87.9 million to $4.1 million. As a result, $4.1 million is included in Non-current Restricted Cash and Cash Equivalents on our Consolidated Balance Sheets.

Pipe Coating Purchase Order

In January 2007, CCTP entered into a purchase order with The Bayou Companies, LLC (“Bayou”) for concrete weight coating on approximately 43 miles of the Creole Trail Pipeline. Payments made by CCTP to Bayou for work performed under the purchase order are not expected to exceed $22.3 million. CCTP may at any time terminate, for convenience, Bayou’s performance to be effective upon receipt of a written notice and payment for items provided or services performed prior to termination. Such work commenced in March 2007 and is expected to be fully completed in July 2007.

15

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

Pipeline Construction Agreements

In January 2007, CCTP entered into a construction agreement with Sheehan Pipe Line Construction Company (“Sheehan”) for the construction of approximately 36 miles of Phase 1 of the Creole Trail Pipeline (consisting of 78 miles of natural gas pipeline). Under the terms of the agreement, Sheehan will provide CCTP with equipment, labor, inspection, manufacture, fabrication, installation, delivery, transportation, storage, assembly and construction services in connection with the Creole Trail pipeline. Payments anticipated to be made by CCTP to Sheehan for work performed under the agreement are not expected to exceed $65.6 million with a 5% retainage that is held back from each invoice to be paid upon final completion. CCTP may at any time terminate, for convenience, Sheehan’s performance effective upon receipt of a written notice by Sheehan and payment for items provided or services performed prior to termination. Such work is expected to commence in July 2007 and is expected to be fully complete in March 2008.

In January 2007, CCTP entered into an agreement with Sunland Construction, Inc. (“Sunland”) for the construction of approximately 23 miles of Phase 1 of the Creole Trail Pipeline. Under the terms of the agreement, Sunland will provide CCTP with equipment, labor, inspection, manufacture, fabrication, installation, delivery, transportation, storage, assembly and construction services in connection with the Creole Trail Pipeline. Payments by CCTP to Sunland under the agreement are not expected to exceed $70.1 million, with a 5% retainage held back from each invoice to be paid upon final completion. CCTP may at any time terminate, for convenience, Sunland’s performance effective upon receipt of a written notice by Sunland and payment for items provided or services performed prior to termination. The agreement is subject to a cancellation fee not to exceed 5% of the estimated contract price. Such work is expected to commence in April 2007 and is expected to be fully complete in May 2008.

In March 2007, CCTP entered into an agreement with Sunland for the construction of approximately 18 miles of the Creole Trail Pipeline. Under the terms of the agreement, Sunland will provide CCTP with equipment, labor, inspection, manufacture, fabrication, installation, delivery, transportation, storage, assembly and construction services in connection with the Creole Trail Pipeline. Payments by CCTP to Sunland under the agreement are not expected to exceed $43.6 million, with a 5% retainage held back from each invoice to be paid upon final completion. CCTP may at any time terminate, for convenience, Sunland’s performance effective upon receipt of a written notice by Sunland, payment for items provided or services performed prior to termination. The agreement is subject to a cancellation fee not to exceed 2% of the estimated contract price. Such work is expected to commence in June 2007 and is expected to be fully complete in May 2008.

NOTE 14—Supplemental Cash Flow Information and Disclosures of Non-Cash Transactions

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

	Three Months Ended March 31,
	2007		2006
Cash paid for interest, net of amounts capitalized	$	3,656	$	13,106
Construction-in-progress additions recorded as accrued liabilities	$	52,544	$	16,525

NOTE 15—Business Segment Information

We have four business segments: LNG receiving terminal, natural gas pipeline, LNG and natural gas marketing and oil and gas exploration and development. These segments reflect lines of business for which

16

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

separate financial information is produced internally and are subject to evaluation by our chief operating decision makers in deciding how to allocate resources.

Our LNG receiving terminal segment is in various stages of developing three LNG receiving terminal projects along the U.S. Gulf Coast at the following locations: Sabine Pass LNG, approximately 91.8% owned (as of March 31, 2007), in western Cameron Parish, Louisiana on the Sabine Pass Channel; 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. In addition, we own a 30% limited partner interest in a fourth project, Freeport LNG, located on Quintana Island near Freeport, Texas.

Our natural gas pipeline segment is in various stages of developing three, 100% owned, natural gas pipelines in connection with our three LNG receiving terminals to provide access to North American natural gas markets.

Our LNG and natural gas marketing segment is in its early stages of development. We intend to purchase LNG from foreign suppliers, arrange transportation of LNG to our network of LNG receiving terminals and other terminals, utilize our revaporization capacity at our LNG receiving terminals and other terminals to revaporize imported LNG, arrange the transportation of revaporized natural gas through our pipelines and other interconnected pipelines, and sell natural gas to buyers. To develop our capacity to resell revaporized natural gas in the future, we are engaged in domestic natural gas purchase and sale, transportation and storage transactions, including financial derivative transactions, as part of our marketing activities.

Our oil and gas exploration and development segment conducts and participates in exploration, development and production activities focused in the shallow waters of the Gulf of Mexico.

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

	Segments
	LNG Receiving Terminal			Natural Gas Pipeline			LNG & Natural Gas Marketing			Oil & Gas Exploration and Development			Corporate and Other(1)			Total Consolidated
As of or for the three months ended March 31, 2007:
Revenues	$	—		$	—		$	(2,088	)	$	832		$	—		$	(1,256	)
Net income (loss) from operations		(6,574	)		(528	)		(5,956	)		332			(17,046	)		(29,772	)
Total assets		2,269,084			131,844			51,265			2,959			457,209			2,912,361
As of or for the three months ended March 31, 2006:
Revenues	$	—		$	—		$	—		$	422		$	—		$	422
Net loss from operations		(8,840	)		(1,669	)		(1,235	)		(978	)		(9,845	)		(22,567	)
Total assets		839,326			800			685			3,263			488,277			1,332,351

(1) Includes corporate activities and certain intercompany eliminations.

17

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

NOTE 16—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 (“1997 Plan”) and the Cheniere Energy, Inc. Amended and Restated 2003 Stock Incentive Plan (“2003 Plan”). Effective January 1, 2006, we adopted SFAS No. 123 (revised 2004), Share-Based Payment, which revised SFAS No. 123 and superseded Accounting Principles Bulletins (“APB”) No. 25. No adjustments to prior periods were made as a result of adopting SFAS No. 123R. SFAS No. 123R requires that all share-based payments to employees be recognized in the 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 method under SFAS No. 123R. We consider many factors when estimating expected forfeitures, including types of awards, employee class and historical experience. The statement was adopted using the modified prospective method of application, which requires compensation expense to be recognized in the financial statements for all unvested stock options beginning in the quarter of adoption.

For the three months ended March 31, 2007 and 2006, the total stock-based compensation expense (net of capitalization) recognized in our net loss was $6.6 million and $5.6 million, respectively. For the three months ended March 31, 2007 and 2006, the total stock-based compensation cost capitalized as part of the cost of capital assets was $0.4 million and $0.3 million, respectively.

The total unrecognized compensation cost at March 31, 2007 relating to non-vested share-based compensation arrangements granted under the 1997 Plan and 2003 Plan, before any capitalization, was $78.6 million. That cost is expected to be recognized over five years, with a weighted average period of 1.8 years.

SFAS No. 123R has no current effect on net cash flow. Once we become a taxpayer, we will recognize cash flow resulting from tax deductions in excess of recognized compensation cost as a financing cash flow. We received total proceeds from the exercise of stock options of $0.8 million and $1.2 million in the three months ended March 31, 2007 and 2006, respectively.

Stock Options

During the first three months of 2007, there were no options issued to purchase shares of our common stock under the 2003 Plan.

We estimate the fair value of stock options under SFAS No. 123R at the date of grant using a Black-Scholes valuation model, which is consistent with the valuation technique we previously utilized to value stock options for the footnote disclosures required under SFAS No. 123. The following table provides the weighted average assumptions used in the Black-Scholes stock option valuation model to value stock options granted in the three months ended March 31, 2007 and 2006, respectively. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of grant. The expected term (estimated period of time outstanding) of stock options granted in 2007 is based on the “simplified” method of estimating expected term for “plain vanilla” stock options allowed by SAB No. 107, Valuation of Share-based Payment Agreements for Public Companies, and varies based on the vesting period and contractual term of the stock option. Expected volatility for stock options granted in 2007 is based on an equally weighted average of the implied volatility of exchange traded stock options on our common stock expiring more than one year from the measurement date, and historical volatility of our common stock for a period equal to the stock option’s expected life. We have not declared dividends on our common stock.

18

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

The table below provides a summary of stock option activity under the combined plans as of March 31, 2007, and changes during the three months then ended:

	Stock Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term	Aggregate Intrinsic Value
	(in thousands)					(in thousands)
Outstanding at January 1, 2007	5,187		$	34.25
Granted	—			—
Exercised	(264	)		27.77
Forfeited or Expired	(16	)		31.63
Outstanding at March 31, 2007	4,907		$	35.91	7.2	$	24,292
Exercisable at March 31, 2007	1,211		$	16.55	4.2	$	19,224

Effective March 28, 2007, we amended certain existing stock option grants to provide for acceleration of vesting upon termination, under certain circumstances, within one year of a change of control event; or upon the death or disability of the stock option holder. We believe that the adoption of this amendment did not have an impact on stock options ultimately expected to vest, and, therefore, did not have a current impact on our financial position, results of operations or cash flows.

Stock and Non-Vested Stock

We have granted stock and non-vested stock to employees, executive officers and outside directors under the 2003 Plan. Under SFAS No. 123R, grants of non-vested stock are accounted for on an intrinsic value basis. No recognition of deferred compensation is made in stockholders’ equity. Instead, the amortization of the calculated value of non-vested stock grants is accounted for as a charge to non-cash compensation and an increase in additional paid-in-capital over the requisite service period.

In January 2007, 628,396 shares having three-year graded vesting were issued to our employees and executive officers in the form of non-vested (restricted) stock awards related to our performance in 2006. In the three months ended March 31, 2007, a total of 51,564 shares of non-vested stock having four-year graded vesting were issued to new and existing employees.

The table below provides a summary of the status of our non-vested shares under the 2003 Plan as of March 31, 2007, and changes during the three months then ended (in thousands except for per share information):

	Non-Vested Shares		Weighted Average Grant-Date Fair Value Per Share
Non-vested at January 1, 2007	555		$	33.97
Granted (1)	680			27.78
Vested	(28	)		37.89
Forfeited	(4	)		30.00
Non-vested at March 31, 2007	1,203		$	30.39

(1) Includes awards of 31,500 non-vested shares granted under the French Addendum to the 2003 Plan, which were not issued and outstanding at March 31, 2007.

19

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

(unaudited)

Share-Based Plan Descriptions and Information

Our 1997 Plan provides for the issuance of stock options to purchase up to 5.0 million shares of our common stock, all of which have been granted. Non-qualified stock options were granted to employees, contract service providers and outside directors. Terms for the remaining unexercised stock options are five years with vesting that generally occurs on a graded basis over three years.

Our 2003 Plan provides for the issuance of up to an aggregate of 11.0 million shares of our common stock. These awards may be in the form of non-qualified stock options, incentive stock options, purchased stock, restricted (non-vested) stock, bonus (unrestricted) stock, stock appreciation rights, phantom stock, and other stock-based performance awards deemed by the Compensation Committee of our Board of Directors to be consistent with the purposes of the 2003 Plan. To date, the only awards made by the Compensation Committee have been in the form of non-qualified stock options, restricted stock and bonus stock. Beginning in 2005, stock options granted to employees as hiring incentives have been granted at the money with 10-year terms and graded vesting over four years. Prior to that time, stock options granted as hiring incentives were granted at the money with five-year terms and graded vesting over three years. Retention grants made to employees provide for exercise prices at or in excess of the stock price on the grant date, 10-year terms and graded vesting over three years, which commences on the fourth anniversary of the grant date. Restricted stock that has been granted as a hiring incentive vests over four years on a graded basis, while restricted stock granted from a bonus pool vests over three years. Shares issued under the 2003 Plan are generally newly issued shares.

NOTE 17—Subsequent Events

On April 16, 2007, the underwriters of the Offering exercised their over-allotment option to purchase 2,025,000 additional common units, which resulted in net proceeds of approximately $39 million to Holdings as the selling unitholder, and reduced our overall ownership interest in Cheniere Partners to approximately 90.6%.

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

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

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

• statements relating to the construction and operation of each of our proposed liquefied natural gas (“LNG”) receiving terminals or our proposed pipelines, or expansions or extensions thereof, including statements concerning the completion or expansion thereof by certain dates or at all, the costs related thereto and certain characteristics, including amounts of regasification and storage capacity, the number of storage tanks and docks, pipeline deliverability and the number of pipeline interconnections, if any;

• statements regarding any financing transactions or arrangements, or ability to enter into such transactions, whether on the part of Cheniere or at the project level;

• statements regarding any terminal use agreement (“TUA”) or other agreement to be entered into or performed substantially in the future, including any cash distributions and revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total regasification capacity that are, or may become subject to, TUAs or other contracts;

• statements regarding counterparties to our TUAs, construction contracts and other contracts;

• statements regarding any business strategy, any business plans or any other plans, forecasts, projections or objectives, any or all of which are subject to change;

• statements regarding any Securities and Exchange Commission (“SEC”) or other governmental or regulatory inquiry or investigation;

• statements regarding legislative, governmental, regulatory, administrative or other public body actions, requirements, permits, 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,” “estimate,” “expect,” “forecast,” “plan,” “project,” “propose,” “strategy” and similar terms and phrases. 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 speak only as of the date of this quarterly report.

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

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, 2006. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. These forward-looking statements are made as of the date of this quarterly report.

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BUSINESS AND OPERATIONS

General

We are currently engaged primarily in the business of developing and constructing, and then owning and operating, a network of three onshore LNG receiving terminals, and related natural gas pipelines, along the Gulf Coast of the United States. We are also developing a business to market LNG and natural gas. To a limited extent, we are also engaged in oil and natural gas exploration and development activities in the Gulf of Mexico. We operate four business activities: LNG receiving terminal, natural gas pipeline, LNG and natural gas marketing, and oil and gas exploration and development.

LNG Receiving Terminal Business

We have focused our LNG receiving terminal development efforts on the following three projects: the Sabine Pass LNG receiving terminal in western Cameron Parish, Louisiana on the Sabine Pass Channel; the Corpus Christi LNG receiving terminal near Corpus Christi, Texas; and the Creole Trail LNG receiving terminal at the mouth of the Calcasieu Channel in central Cameron Parish, Louisiana.

Our ownership interest in the Sabine Pass LNG receiving terminal is held through Cheniere Energy Partners, L.P. (“Cheniere Partners”), a Delaware limited partnership, in which we hold an approximate 90.6% interest as a result of the recent completion of an initial public offering of common units in Cheniere Partners as well as the exercise of the underwriters’ option to purchase additional common units in Cheniere Partners. In turn, Cheniere Partners owns a 100% interest in Sabine Pass LNG, L.P. (“Sabine Pass LNG”), which is currently developing the Sabine Pass LNG receiving terminal. We currently own 100% interests in the Corpus Christi and Creole Trail LNG receiving terminals. In addition, we own a 30% interest in a fourth project, Freeport LNG, located on Quintana Island near Freeport, Texas. The three LNG receiving terminals under development by us have an aggregate designed regasification capacity of approximately 10 billion cubic feet per day (“Bcf/d”), subject to expansion. Sabine Pass LNG has entered into long-term TUAs with Total LNG USA, Inc. (“Total”), Chevron USA, Inc. (“Chevron”) and Cheniere Marketing, Inc. (“Cheniere Marketing”), our wholly-owned subsidiary, for regasification capacity at the Sabine Pass LNG receiving terminal.

Construction of the Sabine Pass LNG receiving terminal commenced in March 2005, and we anticipate commencing operations during the second quarter of 2008. We will contemplate making a final investment decision to complete construction of the Corpus Christi LNG receiving terminal and commence construction of the Creole Trail LNG receiving terminal upon, among other things, achieving acceptable commercial arrangements and arranging appropriate financing.

Natural Gas Pipeline Business

We anticipate developing natural gas pipelines from each of our three LNG receiving terminals to provide optimal access to North American natural gas markets. We anticipate that construction of the Sabine Pass Pipeline will commence in the second quarter of 2007 and that operations will commence in the fourth quarter of 2007. We anticipate that construction of Phase 1 of the Creole Trail Pipeline (consisting of 78 miles of natural gas pipeline) will commence in the second quarter of 2007 and that Phase 1 operations will commence in the second quarter of 2008. Construction contracts for the Corpus Christi Pipeline have not been negotiated.

LNG and Natural Gas Marketing Business

Our LNG and natural gas marketing business is in its early stages of development. We intend to purchase LNG from foreign suppliers, arrange the transportation of LNG to our network of LNG receiving terminals, utilize Cheniere Marketing’s capacity at our LNG receiving terminals to revaporize imported LNG, arrange the transportation of revaporized natural gas through our pipelines and other interconnected pipelines, and sell natural gas to buyers. Alternatively, we may purchase LNG from foreign suppliers and sell the LNG to foreign purchasers if more favorable economic conditions exist in those markets. To develop our capability to resell revaporized natural gas in the future, we are engaging in domestic natural gas purchase and sale, transportation and storage transactions, including financial derivative transactions, as part of our marketing activities.

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Oil and Gas Exploration and Development Business

Although our focus is primarily on the development of LNG-related businesses, we continue to be involved to a limited extent in oil and gas exploration, development and production activities focused in the shallow waters of the Gulf of Mexico.

LIQUIDITY AND CAPITAL RESOURCES

We are primarily engaged in LNG-related business activities. Our three LNG receiving terminal projects, as well as our proposed pipelines, will require significant amounts of capital and are subject to risks and delays in completion. In addition, our marketing business will need a substantial amount of capital for hiring employees, satisfying creditworthiness requirements of contracts and developing the systems necessary to implement our business strategy.

We have obtained financing and approval of our board of directors to construct the following projects, as more fully described below: Phase 1 and Phase 2–Stage 1 of the Sabine Pass LNG receiving terminal; the Sabine Pass Pipeline; and Phase 1 of the Creole Trail Pipeline. The estimated costs of these projects, before financing costs, are, respectively, $1.4 billion to $1.5 billion, $100 million, and $400 million to $450 million.

As of March 31, 2007, we had an unrestricted Cash and Cash Equivalents balance of $583.6 million. In addition, we have $1.2 billion in Restricted Cash, Cash Equivalents and U.S. treasury securities, including $738.8 million for the remaining construction costs of the initial phase (“Phase 1”) and the first stage of the second phase (“Phase 2–Stage 1”) of the Sabine Pass LNG receiving terminal, $353.7 million for interest payments through May 2009 related to the Sabine Pass LNG notes and $98.4 million for cash distributions through June 2009 to the common unitholders of Cheniere Partners and related distributions to its general partner. As a result, we believe that we have adequate financial resources available to us to implement the currently approved projects described above. Our LNG-related business activities are not expected to begin to operate and generate significant cash flows before 2008.

Our LNG Receiving Terminals

Sabine Pass LNG

Customer TUAs

Each of the customers at the Sabine Pass LNG receiving terminal must make capacity payments under its TUA on a “firm commitment” basis, which means that the customer will be obligated to pay the full contracted amount of monthly capacity fees whether or not it uses any of its reserved capacity. Provided the Sabine Pass LNG receiving terminal has achieved commercial operation at 2.0 Bcf/d, which we expect will occur during the second quarter of 2008, these “firm commitment” TUA payments will be made by the following customers:

• Total has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly payments to Sabine Pass LNG aggregating approximately $125 million per year for 20 years commencing April 1, 2009. Total, S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions;

• Chevron has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly payments to Sabine Pass LNG aggregating approximately $125 million per year for 20 years commencing not later than July 1, 2009. Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron; and

• Cheniere Marketing has reserved approximately 2.0 Bcf/d of regasification capacity, is entitled to use any capacity not utilized by Total and Chevron and has agreed to make monthly payments to Sabine Pass LNG aggregating approximately $250 million per year for at least 19 years commencing January 1, 2009, plus payments of $5 million per month during an initial commercial operations ramp-up period in 2008. We have guaranteed Cheniere Marketing’s obligations under its TUA.

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Each of Total and Chevron has paid us $20 million in nonrefundable advance capacity reservation fees, which will be amortized over a 10-year period as a reduction of each customer’s regasification capacity fees payable under its TUA.

Construction of Receiving Terminal

The Sabine Pass LNG terminal is being constructed in two phases. Phase 1 of the Sabine Pass LNG receiving terminal was designed with an initial regasification capacity of 2.6 Bcf/d and three LNG storage tanks with an aggregate LNG storage capacity of 10.1 billion cubic feet (“Bcf”). Construction of Phase 1 began in March 2005. We estimate the cost to construct Phase 1 of the Sabine Pass LNG receiving terminal will be approximately $900 million to $950 million, before financing costs. As of March 31, 2007, we had paid $615.0 million of Phase 1 construction costs.

Phase 2–Stage 1 of the development of the Sabine Pass LNG receiving terminal is designed to increase the regasification capacity from 2.6 Bcf/d to 4.0 Bcf/d by adding two LNG storage tanks, additional vaporizers and related facilities. We estimate the cost to construct Phase 2–Stage 1 of the Sabine Pass LNG receiving terminal will be approximately $500 million to $550 million, before financing costs. As of March 31, 2007, we had paid $73.5 million of Phase 2–Stage 1 construction costs.

We estimate that the aggregate cost to complete construction of Phase 1 and Phase 2–Stage 1 of the Sabine Pass LNG receiving terminal will be approximately $1.4 billion to $1.5 billion, before financing costs. Our cost estimates are subject to change due to such items as cost overruns, change orders, increased component and material costs, escalation of labor costs and increased spending to maintain our construction schedule.

We will fund our construction period capital resource requirements from a portion of the $2,032 million in net proceeds received from Sabine Pass LNG’s issuance in November 2006 of senior secured notes (the “Sabine Pass LNG notes”). We placed $335 million of the net proceeds in a reserve account to fund scheduled interest payments on the Sabine Pass LNG notes through May 2009. We also placed approximately $887 million in a construction account, which, until satisfaction of construction completion milestones, will only be applied to pay construction and startup costs of the Sabine Pass LNG receiving terminal and to pay other expenses incidental for us to complete construction of the project. We used the remaining net proceeds received from the issuance of the Sabine Pass LNG notes to repay indebtedness of Sabine Pass LNG, to make a distribution to Cheniere LNG Holdings, LLC (“Holdings”), our wholly-owned subsidiary, for the repayment of its outstanding term loan and to pay fees and expenses related to the issuance of the Sabine Pass LNG notes.

Phase 1 EPC Agreement

In December 2004, Sabine Pass LNG entered into a lump-sum turnkey engineering, procurement and construction (“EPC”) agreement with Bechtel Corporation (“Bechtel”) for Phase 1 of the Sabine Pass LNG receiving terminal. Except for certain third-party work specified in the EPC agreement, the work to be performed by Bechtel includes all of the work required to achieve substantial completion and final completion of Phase 1 of the Sabine Pass LNG receiving terminal in accordance with the requirements of the EPC agreement. Pursuant to the EPC agreement, Sabine Pass LNG agreed to pay Bechtel a contract price of $646.9 million plus certain reimbursable costs for the work performed under the EPC agreement. This contract price is subject to adjustment for certain costs of materials, contingencies, change orders and other items. As of April 30, 2007, change orders for $132.3 million had been approved, primarily for design changes, increases in costs of materials, insurance costs and costs related to the 2005 hurricanes, increasing the total contract price to $779.2 million.

Phase 2–Stage 1 Construction Agreements

In July 2006, Sabine Pass LNG entered into three construction agreements to facilitate construction of the Phase 2–Stage 1 expansion, as follows:

• EPCM Agreement. Sabine Pass LNG entered into an engineering, procurement, construction and management (“EPCM”) agreement with Bechtel pursuant to which Bechtel will provide: design and

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engineering services for Phase 2–Stage 1 of the Sabine Pass LNG receiving terminal project, except for such portions to be designed by other contractors and suppliers that Sabine Pass LNG contracts with directly; construction management services to manage the construction of the Sabine Pass LNG receiving terminal; and a portion of the construction services. Under the terms of the EPCM agreement, Bechtel will be paid on a cost reimbursable basis, plus a fixed fee in the amount of $18.5 million. A discretionary bonus may be paid to Bechtel at Sabine Pass LNG’s sole discretion upon completion of Phase 2–Stage 1.

• EPC Tank Contract. Sabine Pass LNG entered into an EPC LNG tank contract with Zachry Construction Corporation (“Zachry”) and Diamond LNG LLC (“Diamond”) under which Zachry and Diamond will furnish all plant, labor, materials, tools, supplies, equipment, transportation, supervision, technical, professional and other services, and perform all operations necessary and required to satisfactorily engineer, procure materials for and construct the two Phase 2–Stage 1 LNG storage tanks. The tank contract provides that Zachry and Diamond will receive a lump-sum, total fixed price payment for the two Phase 2–Stage 1 tanks of approximately $140.9 million, which is subject to adjustment based on fluctuations in the cost of labor and certain materials, including the steel used in the Phase 2–Stage 1 tanks, and change orders.

• EPC LNG Unit Rate Soil Contract. Sabine Pass LNG entered into an EPC LNG unit rate soil contract with Remedial Construction Services, L.P. (“Recon”). Under the soil contract, Recon is required to furnish all plant, labor, materials, tools, supplies, equipment, transportation, supervision, technical, professional and other services, and perform all operations necessary and required to satisfactorily conduct soil remediation and improvement on the Phase 2 site, unless otherwise set forth in the soil contract. The soil contract price is based on unit rates. Payments under the soil contract are based on quantities of work performed at unit rates.

Corpus Christi LNG

We currently estimate that the cost of constructing the Corpus Christi LNG receiving terminal will be approximately $650 million to $750 million, before financing costs. This estimate is preliminary and is subject to change. We will contemplate making a final investment decision to complete construction of the Corpus Christi LNG receiving terminal upon, among other things, achieving acceptable commercial arrangements and entering into acceptable financing arrangements.

In order to accelerate the timing of its development of the Corpus Christ LNG receiving terminal, Corpus Christi LNG elected in April 2006 to commence preliminary site work and entered into an engineering, procurement and construction services agreement for such preliminary work which has since been completed.

Creole Trail LNG

We currently estimate that the cost of constructing the Creole Trail LNG receiving terminal will be approximately $850 million to $950 million, before financing costs. Our cost estimate is preliminary and is subject to change. We will contemplate making a final investment decision to commence construction of the Creole Trail LNG receiving terminal upon, among other things, achieving acceptable commercial arrangements and entering into acceptable financing arrangements.

Other LNG Interests

We have a 30% limited partner interest in Freeport LNG. Under the limited partnership agreement of Freeport LNG, development expenses of the Freeport LNG project and other Freeport LNG cash needs generally are to be funded out of Freeport LNG’s own cash flows, borrowings or other sources, and with capital contributions by the limited partners. We did not receive any capital calls, and made no capital contributions, in the first quarter of 2007. In view of the closing of a $383 million private placement of notes in December 2005 by Freeport LNG, we do not

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anticipate any capital calls in the foreseeable future. However, in the event of any future capital call, we will have the option either to contribute the requested capital or to decline to contribute. If we decline to contribute, the other limited partners could elect to make our contribution and receive back twice the amount contributed on our behalf, without interest, before any Freeport LNG cash flows are otherwise distributed to us. We currently expect to evaluate any future Freeport LNG capital calls on a case-by-case basis and to fund additional capital contributions that we elect to make using cash on hand and funds raised through the issuance of our equity or debt securities.

Our Proposed Pipelines

We currently expect to fund the costs of our pipeline projects approved by our board of directors from our existing cash balances.

Sabine Pass Pipeline

We estimate the total cost to construct the Sabine Pass Pipeline to be approximately $100 million. This cost includes work included in the EPC pipeline contract discussed below and costs related to interconnection with third-party pipelines and to right-of-ways. We have sufficient funds to construct the Sabine Pass Pipeline. As of March 31, 2007, we had paid $34.3 million of Sabine Pass Pipeline construction costs.

In February 2006, Cheniere Sabine Pass Pipeline, L.P., our wholly-owned subsidiary, entered into an EPC pipeline contract with Willbros Engineers, Inc. (“Willbros”). Under the EPC pipeline contract, Willbros will provide Cheniere Sabine Pass Pipeline, L.P. with services for the management, engineering, material procurement, construction and construction management of the Sabine Pass Pipeline. Cheniere Sabine Pass Pipeline, L.P. entered into the EPC pipeline contract sufficiently in advance of commencement of physical construction of the pipeline in order to perform detailed engineering and procure materials. This EPC pipeline contract, among other things, provides for a guaranteed maximum price of approximately $67.7 million, subject to adjustment under certain circumstances, as provided in the contract.

Creole Trail Pipeline

We estimate the total cost to construct Phase 1 of the Creole Trail Pipeline to be approximately $400 million to $450 million. Our cost estimate is subject to change due to such items as cost overruns, change orders, delays in construction, increased component and material costs and escalation of labor costs. As of March 31, 2007, we had paid $76.1 million of construction costs for Phase 1 of the Creole Trail Pipeline.

Phase 1 of the Creole Trail Pipeline consists of approximately 78 miles of natural gas pipeline interconnecting with the Sabine Pass Pipeline, running east to the site of the Creole Trail LNG receiving terminal and then north and northeast along a corridor that will allow for interconnection points with existing interstate and intrastate natural gas pipelines in southwest Louisiana.

Cheniere Creole Trail Pipeline, L.P. (“CCTP”), our wholly-owned subsidiary, has issued purchase orders to ILVA S.p.A. and CPW America Co. for the purchase of all of the pipe needed to construct Phase 1 of the Creole Trail Pipeline. In the first quarter of 2007, CCTP entered into construction agreements with Sunland Construction, Inc. and Sheehan Pipe Line Construction Company to construct Phase 1 of the Creole Trail Pipeline. We anticipate that construction of Phase 1 of the Creole Trail Pipeline will commence in the second quarter of 2007 and that Phase 1 operations will commence in the second quarter of 2008.

Corpus Christi Pipeline

Construction contracts for the Corpus Christi Pipeline have not been negotiated.

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Our Marketing Business

We are in the early stages of developing our LNG and natural gas marketing business. We will need to spend funds to develop our marketing business, including capital required to satisfy any creditworthiness requirements under contracts. These costs are expected to be incurred to develop the systems necessary to implement our business strategy and to hire additional employees to conduct our natural gas marketing activities. We expect to fund these expenses with available cash balances. We have committed $40 million initially to our marketing and trading activities, in addition to overhead costs and storage charges. We expect that our committed amount will increase as our LNG and natural gas marketing business develops.

PPM Agreement

In April 2006, Cheniere Marketing entered into a 10-year Gas Purchase and Sale Agreement with PPM Energy, Inc. (“PPM”). Subject to completion of certain of our LNG receiving terminals and pipelines, the agreement provides Cheniere Marketing the ability to sell to PPM up to 600,000 MMBtus of natural gas per day at a Henry Hub-related market index price, and requires Cheniere Marketing to allocate to PPM a portion of the LNG that it procures under certain planned long-term LNG supply agreements.

GDF Agreement

In April 2007, Cheniere Marketing and Gaz de France International Trading S.A.S. (“GDF”), a wholly-owned subsidiary of Gaz de France, executed a Master Ex-Ship LNG Sales Agreement (“Master Agreement”) and related option agreements. The Master Agreement governs the transactions between the parties in the purchase and sale of LNG, but neither party has an obligation under the Master Agreement until both parties have entered into a written order containing the specific quantity, purchase price and other terms of the purchase and sale of the LNG. GDF and Cheniere Marketing entered into a specific order under the Master Agreement providing for the purchase by Cheniere Marketing of up to seven (7) LNG cargoes on an ex-ship basis from GDF for the period from April through October 2008. The purchase price for such cargoes will be 94% of the final New York Mercantile exchange (“NYMEX”) settlement price per million British thermal unit (“MMBtu”) for a specified month, less $0.65 per MMBtu.

In April 2007, Cheniere Marketing and GDF also entered into the GDF Transatlantic Option Agreement (“GDF Option Agreement”) and the Cheniere Transatlantic Option Agreement (“Cheniere Option Agreement”), both of which are to be governed by the terms of the Master Agreement. Under the GDF Option Agreement, Cheniere Marketing granted GDF the option to sell one (1) cargo of LNG per month to Cheniere Marketing, exercisable each month during the Option Period, which is the period beginning on the first day of the month following the later to occur of (i) the commercial start up of the first expansion of the Isle of Grain LNG regasification terminal located in Kent, England and (ii) the commercial start up of the Sabine Pass LNG regasification terminal, continuing through the fifteenth (15th) anniversary of such date. Under the Cheniere Option Agreement, GDF has granted Cheniere Marketing the option to sell one (1) cargo of LNG per month to GDF, exercisable each month during the Option Period.

The effectiveness of the above transactions remain subject to satisfaction of certain conditions, including the approval on or prior to July 1, 2007 of the board of directors of each of the parties, the board of directors of their respective parent companies, or the relevant management committees of a party or its parent company.

Cheniere Energy Partners, L.P. Initial Public Offering

On March 26, 2007, Cheniere Partners and Holdings completed a public offering of a total of 13,500,000 Cheniere Partners’ common units (the “Offering”). Cheniere Partners received $98.4 million of net proceeds upon issuance of 5,054,164 common units to the public in the Offering and Holdings received $164.5 million of net proceeds in connection with its sale of 8,445,836 common units of Cheniere Partners. In April 2007, the

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underwriters of the Offering exercised their over-allotment option with Holdings for the sale of an additional 2,025,000 common units. Holdings received $39.4 million of net proceeds from such sale. The $203.9 million net proceeds received by Holdings is unrestricted as to its use by us while the $98.4 million received by Cheniere Partners is restricted and is invested in U.S. treasury securities to fund a distribution reserve. As a result of the transactions described above, our combined general partner and limited partner ownership interest in Cheniere Partners was reduced to approximately 90.6%.

For each calendar quarter through June 30, 2009, Cheniere Partners will make initial quarterly cash distributions of $0.425 per unit on all outstanding common units, as well as related distributions to the general partner, using cash and earned interest from the distribution reserve that was funded with the $98.4 million of net proceeds that it received from the Offering. During this period, based on our current holdings of approximately 41% of the common units and 100% of the general partner units, we will receive $4.8 million per quarter out of the total $11.4 million quarterly distribution. After June 30, 2009, the distribution reserve is expected to have been depleted, and Cheniere Partners will have to rely on the receipt of operating revenues from its various TUAs to fund future quarterly cash distributions to us and other unitholders.

In addition to the 10,891,357 common units held by Holdings (subsequent to the underwriters’ exercise of their over-allotment option), Holdings holds 135,383,831 subordinated units of Cheniere Partners. Combined, Holdings’ common and subordinated units represent an 88.6% ownership interest in Cheniere Partners. During the subordination period, however, the subordinated units will not be entitled to receive any distributions until the common units have received the initial quarterly distributions plus any arrearages on the initial quarterly distribution from prior quarters. The subordinated units do not accrue arrearages. The subordination period generally will end if:

• Cheniere Partners has earned and paid at least $0.425 on each outstanding common unit, subordinated unit and general partner unit for each of the three consecutive, non-overlapping four-quarter periods ending on or after June 30, 2010; or

• if Cheniere Partners has earned and paid at least $0.638 (150% of the initial quarterly distribution) on each outstanding common unit, subordinated unit and general partner unit for any four consecutive quarters ending on or after June 30, 2008.

In addition to the 3,302,045 general partner units, representing a 2% ownership interest, held by the general partner of Cheniere Partners, a wholly-owned subsidiary of Holdings, the general partner also owns general partner incentive distribution rights, which will entitle it to increasing percentages of the cash that Cheniere Partners distributes in excess of $0.489 per unit per quarter.

Debt Agreements

Sabine Pass LNG Senior Secured Notes

In November 2006, Sabine Pass LNG consummated a private offering of an aggregate principal amount of $2,032 million of Sabine Pass LNG notes, consisting of $550 million of 7 1/4% Senior Secured Notes due 2013 and $1,482 million of 7 1/2% Senior Secured Notes due 2016. Sabine Pass LNG has filed a registration statement with the SEC offering to exchange the unregistered Sabine Pass LNG notes for a like amount of senior secured notes of Sabine Pass LNG which are registered under the Securities Act.

Interest on the Sabine Pass LNG notes is payable semi-annually in arrears on May 30 and November 30 of each year, beginning May 30, 2007. The Sabine Pass LNG notes are secured on a first-priority basis by a security interest in all of its equity interests and substantially all of its operating assets.

Under the indenture governing the Sabine Pass LNG notes, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied. The indenture requires that Sabine

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Pass LNG apply its net operating cash flow (i) first, to fund with monthly deposits its next semiannual payment of approximately $75.5 million of interest on the Sabine Pass LNG notes, and (ii) second, to fund a one-time, permanent debt service reserve fund equal to one semiannual interest payment of approximately $75.5 million on the Sabine Pass LNG notes. Distributions will be permitted only after Phase 1 target completion, as defined in the indenture governing the Sabine Pass LNG notes, or such earlier date as project revenues are received, upon satisfaction of the foregoing funding requirements, after satisfying a fixed charge coverage ratio test of 2:1 and after satisfying other conditions specified in the indenture.

Convertible Senior Unsecured Notes

In July 2005, we consummated a private offering of $325 million aggregate principal amount of Convertible Senior Unsecured Notes due August 1, 2012 to qualified institutional buyers pursuant to Rule 144A under the Securities Act. The notes bear interest at a rate of 2.25% per year. The notes are convertible at any time into our common stock under certain circumstances at an initial conversion rate of 28.2326 per $1,000 principal amount of the notes, which is equal to a conversion price of approximately $35.42 per share. We may redeem some or all of the notes on or before August 1, 2012, for cash equal to 100% of the principal plus any accrued and unpaid interest if in the previous 10 trading days the volume-weighted average price of our common stock exceeds $53.13, subject to adjustment, for at least five consecutive trading days. In the event of such redemption, we will make an additional payment equal to the present value of all remaining scheduled interest payments through August 1, 2012, discounted at the U.S. Treasury rate plus 50 basis points. The indenture governing the notes contains customary reporting requirements.

Concurrently with the issuance of the Convertible Senior Unsecured Notes, we also entered into hedge transactions in the form of an issuer call spread (consisting of a purchase and a sale of call options on our common stock) with an affiliate of the initial purchaser of the notes, having a term of two years and a net cost to us of $75.7 million. These hedge transactions are expected to offset potential dilution from conversion of the notes up to a market price of $70.00 per share. The net cost of the hedge transactions was recorded as a reduction to Additional Paid-in-Capital in accordance with the guidance of Emerging Issues Task Force (“EITF”) Issue 00-19, Accounting for Derivative Financial Instruments Indexed to, and Potentially Settled in, a Company’s Own Stock. Net proceeds from the offering were $239.8 million, after deducting the cost of the hedge transactions, the underwriting discount and related fees. As of March 31, 2007, no holders had elected to convert their notes.

Short-Term Liquidity Needs

We anticipate funding our more immediate liquidity requirements, including expenditures related to the construction of our LNG receiving terminals and pipelines, the growth of our marketing business and our oil and gas exploration, development and exploitation activities, through a combination of any or all of the following:

• cash balances;

• issuances of debt and equity securities, including issuances of common stock pursuant to exercises by the holders of existing stock options;

• LNG receiving terminal capacity reservation fees; and

• collection of receivables.

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Historical Cash Flows

The following table summarizes the changes in our cash and cash equivalents for the three months ended March 31, 2007 and 2006. Additional discussion of the key elements contributing to the changes between periods follows the table (in thousands).

	Three Months Ended March 31,
	2007			2006
Cash provided by (used in):
Operating activities	$	(28,456	)	$	(20,478	)
Investing activities		(113,898	)		(59,770	)
Financing activities		263,011			65,754
Net increase (decrease) in cash and cash equivalents	$	120,657		$	(14,494	)
Cash and cash equivalents at end of period	$	583,620		$	678,098

Operating Activities—Net cash used in operations increased to $28.5 million during the three months ended March 31, 2007 compared to $20.5 million during the three months ended March 31, 2006. This $8.0 million increase was primarily due to continued development of our LNG receiving terminals, pipelines, and marketing and trading businesses and increased costs to support such activities.

Investing Activities—Net cash used in investing activities was $113.9 million during the three months ended March 31, 2007 compared to $59.8 million during the three months ended March 31, 2006. During the first three months of 2007, we invested $160.7 million in constructing our LNG receiving terminals and pipelines, $98.4 million in Restricted Treasury Securities, $6.9 million in advances to contractors and $6.2 million in fixed assets. These investment activities were offset by a $157.2 million use of our restricted cash investments during the first three months of 2007 related to funding of our terminal construction activities discussed above. During the first three months of 2006, we invested $73.8 million relating to Phase 1 construction activities at our Sabine Pass LNG receiving terminal, $1.7 million in fixed assets and $2.0 million in oil and gas drilling activities, respectively. These investment activities were partially offset by a $17.2 million use of our restricted cash investments during the first three months of 2006 related to funding of our Sabine Pass LNG receiving terminal construction activities discussed above and to make payments of interest and principal relating to the Holdings’ term loan outstanding at that time.

Financing Activities—Net cash provided by financing activities was $263.0 million during the three months ended March 31, 2007 compared to $65.8 million during the three months period ended March 31, 2006. During the first three months of 2007, we received $164.5 million in net proceeds from the sale of common units in Cheniere Partners and $98.4 million in net proceeds from the issuance of Cheniere Partners common units to minority owners. See Note 2—“Initial Public Offering of Cheniere Energy Partners, L.P. and Minority Interest” of our Notes to Consolidated Financial Statements for further discussion. During the first three months of 2006, we received proceeds from borrowings under the Sabine Pass LNG credit facility totaling $70.0 million and $1.2 million received from the issuance of common stock related to stock option exercises. These proceeds were partially offset by a $1.5 million Holdings’ term loan principal payment and $3.0 million in debt issuance costs related to the Sabine Pass credit facility, which became due upon the first borrowing under the facility.

Issuances of Common Stock

During the first three months of 2007, a total of 95,996 shares of our common stock were issued pursuant to the exercise of stock options, resulting in net cash proceeds of $0.8 million. In addition, 162,248 shares of common stock were issued in satisfaction of cashless exercises of options to purchase 168,666 shares of common stock.

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In January 2007, 628,396 shares of our common stock were issued to our employees and executive officers in the form of non-vested (restricted) stock awards related to our performance in 2006. During the first three months of 2007, we issued an additional 51,564 shares of non-vested restricted stock to new and existing employees.

Off-Balance Sheet Arrangements

As of March 31, 2007, we had no off-balance sheet debt or other such unrecorded obligations, and we have not guaranteed the debt of any other party.

RESULTS OF OPERATIONS

Three Months Ended March 31, 2007

vs. Three Months Ended March 31, 2006

Consolidated Results (in thousands):

	Three Months Ended March 31, 2007
	LNG Receiving Terminal			Natural Gas Pipeline			LNG & Natural Gas Marketing			Oil & Gas Exploration & Development			Corporate & Other			Consolidated
Revenue	$	—		$	—		$	(2,088	)	$	832		$	—		$	(1,256	)
Operating costs and expenses
LNG receiving terminal and pipeline development expenses		5,298			456			—			—			—			5,754
Exploration costs		—			—			—			359			—			359
Oil and gas production costs		—			—			—			67			—			67
Depreciation, depletion and amortization		45			—			103			90			837			1,075
General and administrative expenses		1,231			72			3,765			(16	)		16,209			21,261
Total operating costs and expenses		6,574			528			3,868			500			17,046			28,516
Income (loss) from operations		(6,574	)		(528	)		(5,956	)		332			(17,046	)		(29,772	)
Interest expense		(23,393	)		(211	)		—			—			(2,822	)		(26,426	)
Interest income		14,845			—			498			3			6,236			21,582
Income (loss) before income taxes and minority interest		(15,122	)		(739	)		(5,458	)		335			(13,632	)		(34,616	)
Minority interest		60			—			—			—			—			60
Net income (loss)	$	(15,062	)	$	(739	)	$	(5,458	)	$	335		$	(13,632	)	$	(34,556	)

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	Three Months Ended March 31, 2006
	LNG Receiving Terminal			Natural Gas Pipeline			LNG & Natural Gas Marketing			Oil & Gas Exploration & Development			Corporate & Other			Consolidated
Revenue	$	—		$	—		$	—		$	422		$	—		$	422
Operating costs and expenses
LNG receiving terminal and pipeline development expenses		6,644			1,669			—			—			—			8,313
Exploration costs		—			—			—			838			—			838
Oil and gas production costs		—			—			—			51			—			51
Depreciation, depletion and amortization		30			—			—			59			517			606
General and administrative expenses		2,166			—			1,235			452			9,328			13,181
Total operating costs and expenses		8,840			1,669			1,235			1,400			9,845			22,989
Loss from operations		(8,840	)		(1,669	)		(1,235	)		(978	)		(9,845	)		(22,567	)
Derivative gain		761			—			—			—			—			761
Interest expense		(6,466	)		—			—			—			(4,672	)		(11,138	)
Interest income		1,881			—			—			—			7,663			9,544
Other income		—			—			—			176			—			176
Loss before income taxes		(12,664	)		(1,669	)		(1,235	)		(802	)		(6,854	)		(23,224	)
Income tax benefit		—			—			—			—			7,413			7,413
Net income (loss)	$	(12,664	)	$	(1,669	)	$	(1,235	)	$	(802	)	$	559		$	(15,811	)

Financial results for the first quarter of 2007 reflect a net loss of $34.6 million, or $0.63 per share (basic and diluted), compared to a net loss of $15.8 million, or $0.29 per share (basic and diluted), for the first quarter of 2006.

The major factors contributing to our net loss of $34.6 million during the first quarter of 2007 were LNG terminal and pipeline development expenses of $5.8 million, general and administrative expenses of $21.3 million and interest expense of $26.4 million. These expenses were partially offset by interest income of $21.6 million. The major factors contributing to our net loss of $15.8 million during the first quarter of 2006 were LNG terminal and pipeline development expenses of $8.3 million, general and administrative expenses of $13.2 million and interest expense of $11.1 million. These expenses were partially offset by interest income of $9.5 million and a $7.4 million tax benefit that was recorded in accordance with SFAS No. 109.

LNG Receiving Terminal Segment

Financial results for our LNG receiving terminal segment for the first quarter of 2007 reflect a net loss of $15.1 million, compared to a net loss of $12.7 million for the first quarter of 2006.

LNG receiving terminal development expenses were 19.7% lower in the first quarter of 2007 with expenses of $5.3 million compared to the first quarter 2006 expenses of $6.6 million. Our development expenses include professional costs associated with front-end engineering and design work, obtaining orders from the FERC authorizing construction of our facilities and other required permitting for our planned LNG receiving terminals. In addition, development expenses include other costs related to employees directly involved in our development activities and land site rentals.

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LNG receiving terminal development expenses were mainly attributable to our Creole Trail and Corpus Christi LNG receiving terminal projects and Phase 2—Stage 1 of the Sabine Pass LNG receiving terminal. In April 2006, we elected to commence preliminary site work at the site of our Corpus Christi LNG receiving terminal and, in July 2006, we commenced construction activities for Phase 2—Stage 1 of our Sabine Pass LNG receiving terminal. As a result, first quarter 2007 development expenses decreased by $3.0 million compared to the first quarter 2006. In the first quarter 2007, development expenses relating to our Creole Trail LNG receiving terminal also decreased by $1.0 million compared to the same period in 2006, as development activities for the project had been reduced. In addition, our LNG staff increased from an average of 45 employees in the first quarter of 2006 to an average of 89 employees in the first quarter of 2007 resulting in an increase in total compensation expense from $2.7 million in 2006 to $5.6 million in 2007.

General and administrative (“G&A”) expenses were 45.5% lower in the first quarter of 2007 with expenses of $1.2 million compared to expenses in the first quarter 2006 of $2.2 million. We incurred $0.4 million in Hurricane Rita relief efforts associated with our LNG terminals in the first quarter of 2006 that we did not occur in the first quarter of 2007. In addition, we incurred a $0.2 million reduction for capitalized labor associated with a terminal operations management system that is being implemented for our LNG receiving terminals in the first quarter of 2007, compared to expenses of $0.3 million in the first quarter of 2006.

The increase in interest income to $14.8 million in the first quarter of 2007 compared to $1.9 million in the first quarter of 2006 was due to an increase in average invested cash balances from the Sabine Pass LNG notes issued in November 2006. Similarly, the increase in interest expense, net of capitalization, from $23.4 million in the first quarter of 2007 to $6.5 million for the same period in 2006 was due to the issuance of the Sabine Pass LNG notes.

Natural Gas Pipeline Segment

Financial results for our natural gas pipeline segment for the first quarter of 2007 reflect a net loss of $0.7 million, compared to a net loss of $1.7 million for the first quarter of 2006.

Natural gas pipeline development expenses decreased to $0.5 million in the first quarter of 2007 compared to expenses of $1.7 million in the first quarter of 2006. In June 2006, we received approval from the FERC to construct and operate our Creole Trail Pipeline and a portion of our Sabine Pass Pipeline. In addition, we received approval in December 2006 to reduce our Creole Trail Pipeline capacity to a single pipeline. As a result, first quarter 2007 development expenses decreased $1.1 million when compared to the first quarter of 2006.

LNG and Natural Gas Marketing Segment

Financial results for our LNG and natural gas marketing segment for the first quarter of 2007 reflect a net loss of $5.5 million, compared to a net loss of $1.2 for the first quarter of 2006. We incurred a marketing and trading loss of $2.1 million in the first quarter of 2007 compared to zero in the first quarter of 2006. We commenced natural gas trading activities in December 2006.

G&A expenses increased to $3.8 million in the first quarter of 2007 compared to expenses of $1.2 million in the first quarter of 2006. G&A expenses in the first quarter of 2007 were primarily related to employee costs. Our marketing staff increased from an average of 6 employees in the first quarter of 2006 to an average of 34 employees in the first quarter of 2007, resulting in an increase in total compensation expense, including bonus accruals, of $3.1 million in the first quarter of 2007 to $0.7 million in the first quarter of 2006.

We earned $0.5 million in interest income in the first quarter of 2007 compared to zero in the first quarter of 2006 due to an increase in average invested cash balances as a result of our initial $40.0 million investment in our marketing and trading activities in November 2006.

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Oil and Gas Exploration and Development Segment

Financial results for our oil and gas exploration and development segment for the first quarter of 2007 reflect net income of $0.3 million, compared to a net loss of $0.8 million for the first quarter of 2006. The increase in net income is primarily due to a decrease in exploration costs and an increase in production volumes from the addition of successful wells in 2006.

Corporate and Other

Financial results for corporate and other activities for the first quarter of 2007 reflect a net loss of $13.6 million, compared to a net income of $0.6 million for the first quarter of 2006.

G&A expenses increased 74.2% to $16.2 million in the first quarter of 2007 compared to $9.3 million in the first quarter of 2006. Our corporate staff increased from an average of 70 employees in the first quarter of 2006 to an average of 128 employees in the first quarter of 2007, resulting in total compensation, including bonus accruals, of $11.0 million in the first quarter of 2007 compared to $5.9 million in the first quarter of 2006. In addition, we incurred $1.4 million in legal fees associated with the Offering of Cheniere Partners in the first quarter of 2007.

Interest income decreased to $6.2 million in the first quarter of 2007 compared to $7.7 million in the first quarter of 2006 due to a decrease in average invested cash balances, primarily as a result of the termination of the Term Loan in November 2006.

A tax benefit of $7.4 million was recognized in the first quarter of 2006 relating to the portion of the change in our tax asset valuation account that is allocable to the deferred income tax on items reported in accumulated other comprehensive income on derivative instruments in accordance with SFAS No. 109, Accounting for Income Taxes, and EITF Abstracts, Topic D-32.

Interest expense was $2.8 million in the first quarter of 2007 compared to $4.7 million in the first quarter of 2006. The decrease was due to a reduction in the amount of outstanding indebtedness from the termination of the Term Loan in November 2006.

OTHER MATTERS

Critical Accounting Estimates and Policies

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 the specific set of circumstances existing in our business. We make every effort to comply properly 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.

Accounting for LNG Activities

Generally, we begin capitalizing the costs of our LNG receiving terminals and related pipelines once the individual project meets the following criteria: (i) regulatory approval has been received, (ii) financing for the project is available and (iii) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a project are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals, and other preliminary investigation and development activities related to our LNG receiving terminals and related pipelines.

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Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land costs, costs of lease options and the costs of certain permits, which are capitalized as intangible LNG assets. The costs of lease options are amortized over the life of the lease once it is obtained. If no lease is obtained, the costs are expensed. Site rental costs and related amortization of capitalized options have been capitalized during the construction period through the end of 2005. Beginning in 2006, such costs have been expensed as required by the FASB Staff Position No. 13-1.

During the construction periods of our LNG receiving terminals, we capitalize interest and other related debt costs in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 34, Capitalization of Interest Cost, as amended by SFAS No. 58, Capitalization of Interest Cost in Financial Statements That Include Investments Accounted for by the Equity Method (an Amendment of FASB Statement No. 34). Upon commencement of operations, capitalized interest, as a component of the total cost, will be amortized over the estimated useful life of the asset.

Regulated Operations

Our developing natural gas pipeline business is subject to the jurisdiction of the FERC in accordance with the Natural Gas Act of 1938 and the Natural Gas Policy Act of 1978, and we have determined that certain of our pipeline systems to be constructed have met the criteria set forth in SFAS No. 71. Accordingly, we have applied the provisions of SFAS No. 71 to the affected pipeline subsidiaries beginning in the second quarter of 2006.

Our application of SFAS No. 71 is based on the current regulatory environment, our current projected tariff rates, and our ability to collect those rates. Future regulatory developments and rate cases could impact this accounting. Although discounting of our maximum tariff rates may occur, we believe the standards required by SFAS No. 71 for its application are met and the use of regulatory accounting under SFAS No. 71 best reflects the results of future operations in the economic environment in which we will operate. Regulatory accounting requires us to record assets and liabilities that result from the rate-making process that would not be recorded under GAAP for non-regulated entities. We will continue to evaluate the application of regulatory accounting principles based on on-going changes in the regulatory and economic environment. Items that may influence our assessment are:

• inability to recover cost increases due to rate caps and rate case moratoriums;

• inability to recover capitalized costs, including an adequate return on those costs through the rate-making process and the FERC proceedings;

• excess capacity;

• increased competition and discounting in the markets we serve; and

• impacts of ongoing regulatory initiatives in the natural gas industry.

Natural gas pipeline costs include amounts capitalized as an Allowance for Funds Used During Construction (“AFUDC”). The rates used in the calculation of AFUDC are determined in accordance with guidelines established by the FERC. AFUDC represents the cost of debt and equity funds used to finance our natural gas pipeline additions during construction. AFUDC is capitalized as a part of the cost of our natural gas pipelines. Under regulatory rate practices, we generally are permitted to recover AFUDC, and a fair return thereon, through our rate base after our natural gas pipelines are placed in service.

Revenue Recognition

LNG receiving terminal capacity reservation fees are recognized as revenue over the term of the respective TUAs. Advance capacity reservation fees are deferred initially.

Cash Flow Hedges

As defined in SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, cash flow hedge transactions hedge the exposure to variability in expected future cash flows (i.e., in our case, the variability

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of floating interest rate exposure). In the case of cash flow hedges, the hedged item (the underlying risk) is generally unrecognized (i.e., not recorded on the balance sheet prior to settlement), and any changes in the fair value, therefore, will not be recorded within earnings. Conceptually, if a cash flow hedge is effective, this means that a variable, such as a movement in interest rates, has been effectively fixed so that any fluctuations will have no net result on either cash flows or earnings. Therefore, if the changes in fair value of the hedged item are not recorded in earnings, then the changes in fair value of the hedging instrument (the derivative) must also be excluded from the income statement or else a one-sided net impact on earnings will be reported, despite the fact that the establishment of the effective hedge results in no net economic impact. To prevent such a scenario from occurring, SFAS No. 133 requires that the fair value of a derivative instrument designated as a cash flow hedge be recorded as an asset or liability on the balance sheet, but with the offset reported as part of OCI, to the extent that the hedge is effective. We assess, both at the inception of each hedge and on an on-going basis, whether derivatives that are used in our hedging transactions are highly effective in offsetting changes in cash flows of the hedged items. On an on-going basis, we monitor the actual dollar offset of the hedges’ market values compared to hypothetical cash flow hedges. Any ineffective portion will be reflected in earnings. Ineffectiveness is the amount of gains or losses from derivative instruments that are not offset by corresponding and opposite gains or losses on the expected future transaction.

Goodwill

Goodwill is accounted for in accordance with SFAS No. 142, Goodwill and Other Intangible Assets. We perform an annual goodwill impairment review in the fourth quarter of each year, although we may perform a goodwill impairment review more frequently whenever events or circumstances indicate that the carrying value may not be recoverable.

Share-Based Compensation Expense

Effective January 1, 2006, we adopted the fair value recognition provisions of SFAS No. 123R using the modified prospective transition method. Under this method, we recognize compensation expense for all share-based payments granted after January 1, 2006 and prior to, but not yet vested as of, January 1, 2006, in accordance with SFAS 123R using the Black-Scholes option valuation model. Under the fair value recognition provisions of SFAS 123R, we recognize stock-based compensation net of an estimated forfeiture rate and only recognize compensation cost for those shares expected to vest on a straight-line basis over the requisite service period of the award.

Determining the appropriate fair value model and calculating the fair value of share-based payment awards require the input of highly subjective assumptions, including the expected life of the share-based payment awards and stock price volatility. We believe that implied volatility, calculated based on traded options of our common stock, combined with historical volatility is an appropriate indicator of expected volatility and future stock price trends. Therefore, expected volatility for the quarter ended March 31, 2007 was based on a combination of implied and historical volatilities. The assumptions used in calculating the fair value of share-based payment awards represent our best estimates, but these estimates involve inherent uncertainties and the application of management judgment. As a result, if factors change and we use different assumptions, our stock-based compensation expense could be materially different in the future. In addition, we are required to estimate the expected forfeiture rate and only recognize expense for those shares expected to vest. If our actual forfeiture rate is materially different from our estimate, the stock-based compensation expense could be significantly different from what we have recorded in the current period. See Note 16—”Share-Based Compensation” of our Notes to Consolidated Financial Statements for a further discussion on share-based compensation.

New Accounting Pronouncements

In July 2006, the FASB issued FASB Interpretation No. 48 (“FIN No. 48”), Accounting for Uncertainty in Income Taxes—An Interpretation of FASB Statement No. 109. FIN No. 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with SFAS No. 109, Accounting

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for Income Taxes. It prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This new standard also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. The provisions of FIN No. 48 are to be applied to all tax positions upon initial adoption of this standard. Only tax positions that meet the more likely-than-not recognition threshold at the effective date may be recognized or continue to be recognized upon adoption of FIN No. 48. The cumulative effect of applying the provisions of FIN No. 48 should be reported as an adjustment to the opening balance of retained earnings (or other appropriate components of equity or net assets in the statement of financial position) for that fiscal year. We adopted FIN No. 48 in the first quarter of 2007. The adoption of FIN No. 48 had no material impact on our financial position, results of operations or cash flows.

In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities—Including an amendment of FASB Statement No. 115. This statement permits entities to choose to measure many financial instruments and certain other items at fair value. The objective is to improve financial reporting by providing entities with the opportunity to mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. This statement is expected to expand the use of fair value measurement, which is consistent with the FASB’s long-term measurement objectives for accounting for financial instruments. This statement is effective as of the beginning of an entity’s first fiscal year that begins after November 15, 2007, although earlier adoption is permitted. Management has not determined the effect that adopting this statement would have on our financial condition or results of operations.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Oil and Gas Exploration Commodity Price Risk

We produce and sell natural gas, crude oil and condensate. As a result, our financial results can be affected as these commodity prices fluctuate widely in response to changing market forces. We have not entered into any derivative transactions related to our oil and gas exploration activities.

Marketing and Trading Commodity Price Risk

Through Cheniere Marketing, we conduct natural gas marketing and trading activities. We use value at risk (“VaR”) ad other methodologies for market risk measurement and control purposes. For the three months ended March 31, 2007, the one-day VaR with a 95% confidence interval of our marketing and trading positions averaged $0.5 million. At March 31, 2007, the one-day VaR of our marketing and trading positions was $0.3 million.

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 Sheet.

Item 4. Disclosure 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 of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that our disclosure controls and procedures are effective.

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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 are, and in the future may 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 and legal counsel, as of March 31, 2007, there were no known threatened or 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.

As previously disclosed, we received a letter dated December 17, 2004 advising us of a nonpublic, informal inquiry being conducted by the SEC. On August 9, 2005, the SEC informed us that it had issued a formal order to commence a nonpublic factual investigation of actions and communications by Cheniere, its current or former directors, officers and employees and other persons in connection with our agreements and negotiations with Chevron, the Company’s December 2004 public offering of common stock, and trading in our securities. The scope, focus and subject matter of the SEC investigation may change from time to time, and we may be unaware of matters under consideration by the SEC. We have cooperated fully with the SEC informal inquiry and intend to continue cooperating fully with the SEC in its investigation. We have not received any communication from the SEC with regard to this matter since September 2005.

Item 5. Other Information

Through an indirect wholly-owned subsidiary, we previously held a minority interest in J & S Cheniere S.A. (“J & S Cheniere”), which was formed to engage in LNG transportation and trading through the utilization and management of LNG tankers, two of which are currently under construction and described in more detail below. The remaining majority interest in J & S Cheniere was held by Mercuria Energy Holding B.V. (“Mercuria”), a Netherlands corporation formerly known as J & S Energy Holding B.V. and affiliated with J & S Trading Company, Ltd., an international petroleum trading and marketing company. Our minority interest was initially held under an original shareholders agreement with Mercuria that was amended and restated on May 8, 2007 (“J & S amended shareholders agreement”). Pursuant to the J & S amended shareholders agreement, we increased our minority interest in J & S Cheniere to 49%. The remaining 51% of the shares of J & S Cheniere continues to be held by Mercuria.

In August 2004, J & S Cheniere executed a time charter agreement for an LNG tanker with a term of up to 10 years with Kawasaki Kisen Kaisha, Ltd. (“K-Line”) to charter a new build, 145,000 cubic meter-capacity LNG tanker being constructed by Kawasaki Shipbuilding Corporation. The LNG tanker is expected to be delivered in the fourth quarter of 2007. In August 2004, J & S Cheniere also executed a time charter agreement for an LNG tanker with a term of up to 10 years with a joint venture company established by K-Line, Shoei Kisen Kaisha, Ltd. and others to charter a new build, 154,200 cubic meter-capacity LNG tanker being constructed by Imabari Shipbuilding Co., Ltd. The LNG tanker is expected to be delivered in the second quarter of 2008.

Under the J & S amended shareholders agreement, the two shareholders have each committed to loan $25 million to J & S Cheniere for the purpose of collateralizing certain obligations of J & S Cheniere relating to the two K-Line LNG tanker time charters. Mercuria has also agreed to the cancellation of prior loans to J & S Cheniere. This agreement further provides for priority of distributions in that Mercuria is entitled to receive from J & S Cheniere the first $15.9 million of distributions, after which our subsidiary will be entitled to the next $10 million of distributions, and thereafter distributions will be made pro rata in accordance with the number of

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shares owned by each shareholder. Each shareholder has the right to appoint half of the board of directors of J & S Cheniere. Either shareholder may propose a buy-out price to the other at any time, in which case the other shareholder must elect, in accordance with the J & S amended shareholders agreement, either to buy or sell at the proposed price. The selling shareholder would still be entitled to receive from J & S Cheniere any remaining unpaid portion of such shareholder’s respective $15.9 million or $10 million distribution entitlement. The J & S amended shareholders agreement also provides Mercuria the right to acquire all of our J & S Cheniere shares in the event that we experience a change in control (defined in the shareholders agreement to be a change in a majority of our board, the acquisition of more than 40% of our outstanding common stock other than as approved by our board of directors, or a merger or consolidation that results in 50% or less of the surviving entity’s voting securities being owned by the holders of our voting securities immediately prior to such transaction). The purchase price for such shares would equal the total contributions and loans made by us to J & S Cheniere plus any remaining unpaid portion of our $10 million distribution entitlement, and would be adjusted for our pro rata share of the undistributed amount of profits or losses incurred by J & S Cheniere.

In addition, the J & S amended shareholders agreement terminated a certain December 2003 option agreement that granted J & S Cheniere an option to enter into TUAs reserving up to 200 MMcf/d of capacity at each of the Sabine Pass LNG and Corpus Christi LNG receiving terminals. In replacement of such terminated option, Cheniere Marketing and J & S Cheniere agreed to continue negotiating LNG sale and purchase agreements that would provide for the sale by J & S Cheniere of approximately 78,475,000 MMBtus of stipulated maximum annual LNG reception quantity to Cheniere Marketing for delivery at each of the Sabine Pass LNG receiving terminal and the Corpus Christi LNG receiving terminal. The proposed form of these sale and purchase agreements is attached as an exhibit to the J & S amended shareholders agreement, although there is no binding obligation for the parties to enter into these agreements, and any definitive sale and purchase agreement that is entered into may involve substantially different terms. The form of sale and purchase agreement contemplates an initial five-year term, with up to three additional five-year renewal periods, at the option of J & S Cheniere, upon payment of a $1 million fee for each renewal. As contemplated in the form of sale and purchase agreement, J & S Cheniere would be able to “put” to Cheniere Marketing approximately 78,475,000 MMBtus of stipulated maximum annual LNG reception quantity with a minimum obligation to deliver one cargo per year (approximately 3,200,000 MMBtus of LNG), or pay an agreed amount if such cargo is not delivered, to the Sabine Pass LNG receiving terminal, at a price based on an agreed percentage of the price of natural gas at the NYMEX Henry Hub. It is contemplated that the same terms would apply in connection with the sale and purchase agreement between the parties for delivery of LNG reception quantity to the Corpus Christi LNG receiving terminal. The J & S amended shareholders agreement states that the sale and purchase agreements will contain a provision that, in the event of a sale by either shareholder of its entire interest in J & S Cheniere (other than because of a change of control of us), J & S Cheniere will automatically become obligated under each sale and purchase agreement to deliver, or pay agreed upon amounts if not delivered, to Cheniere Marketing an annual contract quantity equivalent to approximately 78,475,000 MMBtu of annual LNG reception quantity priced in accordance with the pricing provisions contained in such form of sale and purchase agreement.

The form of sale and purchase agreement also contemplates that, in the event that a sale and purchase agreement is terminated by J & S Cheniere because Cheniere Marketing fails to perform its purchase or payment obligations, or becomes bankrupt, or because a change of control of Cheniere has occurred, J & S Cheniere would enter into a TUA with Sabine Pass LNG or Corpus Christi LNG, as applicable, covering approximately 78,475,000 MMbtus of stipulated maximum annual LNG reception quantity for either of the Sabine Pass LNG receiving terminal or the Corpus Christi LNG receiving terminal, as applicable, if such terminal has commenced commercial operation. The form of this potential TUA, which we refer to as the J & S Cheniere contingent TUA, is attached to the form of sale and purchase agreement.

Sabine Pass LNG and Cheniere Marketing have entered into a related letter agreement in which Sabine Pass LNG has agreed to enter into the J & S Cheniere contingent TUA if and when applicable, and Cheniere Marketing has agreed to relinquish 78,475,000 MMBtus of stipulated maximum annual LNG reception quantity (and proportionately reduce its fixed monthly fee) under the Cheniere Marketing TUA if required to allow Sabine

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Pass LNG to satisfy its obligations under the J & S Cheniere contingent TUA. This letter agreement cancels and supersedes the similar November 2006 letter agreement of Sabine Pass LNG and Cheniere Marketing that related to a potential TUA with J & S Cheniere under its now-terminated December 2003 option agreement.

Item 6. Exhibits

(a) Each of the following exhibits is filed herewith:

10.1	Change Order 43 to Lump Sum Turnkey Engineering, Procurement and Construction Agreement dated December 18, 2004, between Sabine Pass LNG, L.P. and Bechtel Corporation (incorporated by reference to Exhibit 10.34 to Sabine Pass LNG, L.P.’s Registration Statement on Form S-4 (SEC file No. 333-138916), filed on April 3, 2007)
10.2	Master Ex-Ship LNG Sales Agreement, dated April 26, 2007, between Cheniere Marketing, Inc. and Gaz de France International Trading S.A.S., including Letter Agreement, dated April 26, 2007, and Specific Order No. 1, dated April 26, 2007
10.3	GDF Transatlantic Option Agreement, dated April 26, 2007, between Cheniere Marketing, Inc. and Gaz de France International Trading S.A.S.
10.4	Change Orders 44 and 45 to Lump Sum Turnkey Engineering, Procurement and Construction Agreement dated December 18, 2004, between Sabine Pass LNG, L.P. and Bechtel Corporation
10.5	Summary of Compensation for Executive officers
10.6	Amended and Restated Shareholders Agreement, dated May 8, 2007, between Mercuria Energy Holding B.V. and Cheniere LNG Services, Inc.
10.7	Master Loan Agreement, dated May 8, 2007, between Cheniere LNG Services, Inc. and J & S Cheniere SA
10.8	Letter Agreement, dated May 8, 2007, between Cheniere Marketing, Inc. and Sabine Pass LNG, L.P.
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

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SIGNATURES

Pursuant to the requirements of the Securities and 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.

/s/    CRAIG K. TOWNSEND        

Vice President and Chief Accounting Officer

(on behalf of the registrant and

as principal accounting officer)

Date: May 8, 2007

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EX-10.2

Exhibit 10.2

MASTER EX-SHIP LNG SALES AGREEMENT

Between

CHENIERE MARKETING, INC.

AND

GAZ DE FRANCE INTERNATIONAL TRADING S.A.S.

INDEX

CLAUSE	SUBJECT
1	Definitions and Interpretation
2	Sale and Purchase; Specific Orders
3	Quantity
4	Delivery Schedule
5	Quality
6	Shipping and LNG Receiving Facilities
7	Ship movements and unloading
8	Measurement, Sampling and Testing
9	Transfer of Title and Risk
10	Price and Payment
11	Taxes and Charges
12	Permissions and Approvals
13	Force Majeure
14	Liabilities
15	Governing Law and Arbitration
16	Safety
17	Term
18	General

Schedule A:	Form of the Specific Order
Schedule B:	Delivery Procedures - Measurement, Sampling and Testing
Schedule C:	Form of Notice of Arrival
Schedule D:	Form of Notice of Readiness
Schedule E:	Form of EX-SHIP Certificate of Volume on Unloading
Schedule F:	Form of EX-SHIP Certificate of Quality on Unloading

MASTER EX-SHIP LNG SALES AGREEMENT

THIS AGREEMENT is dated as of this 26^th day of April, 2007,

BETWEEN:

CHENIERE MARKETING, INC. (“Cheniere”), a company incorporated under the laws of the State of Delaware, U.S.A., with an office at 700 Milam St., Suite 800, Houston, Texas 77002, U.S.A. (“Buyer” or “Seller” as the case may be, as specified in the Specific Order) of the one part, and

GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. (“GDF”), a wholly owned subsidiary company of Gaz de France S.A. incorporated under the laws of France, the registered office of which is situated at 2 rue Curnonsky, 75017 Paris, France and being registered in the Commercial Register under N° RCS 421 292 772 (“Seller” or “Buyer” as the case may be, as specified in the Specific Order) of the other part.

CHENIERE MARKETING, INC. and GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. are herein also referred to individually as a “Party” and collectively as the “Parties”.

This Agreement shall consist of the general terms and conditions herein and the special provisions and/or terms and conditions regarding a specific transaction confirmed in writing in substantially similar form to the pro forma Specific Order attached hereto as Schedule A.

WHEREAS:

A. Either Party may have available for sale LNG during the term of this Agreement;

B. Either Party may wish to purchase LNG during the term of this Agreement and may receive such LNG EX-SHIP at the Discharge Port;

C. The Parties wish to enter into the sale and purchase of LNG in accordance with the following terms and conditions; and

D. This agreement shall serve as the “Master EX-SHIP LNG Agreement” to cover transactions between the Parties which shall be described more specifically by each Specific Order, in the general form attached as Schedule “A”.

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	NOW THIS AGREEMENT WITNESSES as follows:
1.	DEFINITIONS AND INTERPRETATION
1(1)	In this Agreement, unless the context otherwise requires:
	“Adverse Weather Conditions” means weather and/or sea conditions actually experienced that are sufficiently severe to prevent an LNG Ship from proceeding to berth, unloading or departing from berth in accordance with the weather standards prescribed in published regulations in effect at the Discharge Port, or by order of the harbour master.
	“Affected Party” has the meaning set forth in Sub-Clause 18(5).
	“Affiliate” means, with respect to any Person, any other Person (excluding natural persons) that, directly or indirectly, (a) owns or controls the first Person, (b) is owned or controlled by the first Person or (c) is under common ownership or control with the first Person, where “own” means ownership of fifty percent (50%) or more of the equity interests, shares, quotas or rights to distributions on account of equity of the Person and “control” means the direct or indirect power to direct the management or policies of the Person, whether through the ownership of voting securities, by contract or otherwise.
	“Agreement” means the legally binding relationship established by (i) this Master EX-SHIP LNG Sales Agreement (including all Schedules attached hereto) and (ii) the provisions contained in any effective Specific Order.
	“Allowed Laytime” has the meaning set forth in Sub Clause 7(1.2) or Sub Clause 7(2.3) as the case may be.
	“Arrival Period” means, with respect to a Specific Order, the range of time specified in that Specific Order which is the period when the arrival of the LNG Ship at the PBS (or its equivalent) is scheduled.
	“BTU” means a British thermal unit, being the amount of heat equal to 1,055.06 Joule.
	“Business Day” means any day (other than a Saturday and a Sunday) on which banks generally are open for business in the country of Buyer.
	“Cargo Underdelivery Amount” has the meaning set forth in Sub-Clause 4(4).
	“Confidential Information” has the meaning set forth in Sub-Clause 18(2).
	“Day” means a period of twenty-four (24) consecutive hours commencing at 00.00 hours GMT (Greenwich Meridian Time) on any calendar day.
	“Deemed Delivery Amount” has the meaning set forth in Sub-Clause 4(3).

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“Delivery Point” means the point at the Discharge Port where the outlet flanges of the unloading lines of the LNG Ship connect with the inlet flanges of the unloading lines of the LNG Receiving Facilities.

“Demurrage” has the meaning set forth in Sub-Clause 7(8) and is payable at the rate set forth in the Specific Order.

“Discharge Port” means, with respect to a Specific Order, the port where the LNG shall be unloaded, as stated in that Specific Order.

“Dispute” has the meaning set forth in Sub-Clause 15(2).

“Estimated Treating Costs” has the meaning set forth in Sub-Clause 5(2).

“ETA” means, with respect to a given LNG Ship, the estimated time of arrival of such LNG Ship at the Discharge Port.

“Euro(s)” or “EUR” means the single legal currency adopted by those member states of the European Union participating in the third stage of the Economic and Monetary Union.

“European Union” means the European Union as established by the treaty of Rome dated 25 March 1957 (as amended by subsequent treaties) and comprising each member state.

“Execution Date” means the date of this Master EX-SHIP LNG Sales Agreement.

“Expert” means an independent expert appointed to resolve a dispute of a technical nature between the Parties pursuant to Sub-Clause 8(7).

“EX-SHIP” means Delivered Ex-Ship (DES) as per Incoterms 2000 (International Rules for the Interpretation of Trade Terms, as published by the International Chamber of Commerce, edition 2000), as modified herein. Should any specific provision of this Master EX-SHIP LNG Sales Agreement or of a Specific Order conflict with the terms contained in the Incoterms 2000 definition, then the specific provision of the Agreement shall prevail.

“EX-SHIP Certificate of Quality on Unloading” has the meaning set forth in Sub-Clause 8(3), which certificate shall be substantially in the form set forth in Schedule F.

“EX-SHIP Certificate of Volume on Unloading” has the meaning set forth in Sub-Clause 8(2), which certificate shall be substantially in the form set forth in Schedule E.

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“Force Majeure” has the meaning set forth in Sub-Clause 13(1).

“Force Majeure Notice” has the meaning set forth in Sub-Clause 13(1).

“Gross Heating Value (Volume Based)” means depending upon the customary units of measurement used at the place where it is calculated (a) the number of MJ produced by the complete combustion at a constant absolute pressure of one decimal zero one three two five (1.01325) bar of one (1) Standard Cubic Metre of gas at a temperature of fifteen (15) degrees Celsius with excess air at the same temperature and pressure as the gas when the products of combustion are cooled to fifteen (15) degrees Celsius and when the water formed by combustion is condensed to the liquid state and the products of combustion contain the same total mass of water vapour as the gas and air before combustion; and for avoidance of doubt calorific value shall be real as defined in ISO 6976:1995 or (b) the quantity of heat, expressed in BTU, produced by the complete combustion in air of one (1) Cubic Foot of anhydrous gas, at a temperature of sixty (60) degrees Fahrenheit and an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch, with the air at the same temperature and pressure as the gas, after cooling the products of the combustion to the initial temperature of the gas and air and after condensation of the water formed by combustion.

“Gross Heating Value (Mass Based)” means when expressed in MJ/kg, the quantity of heat produced by the complete combustion in dry air of one (1) kilogram mass of dry gas and the condensation of all the water formed, with the initial and final temperature and pressure being fifteen (15) degrees Celsius and one hundred one decimal three two five (101.325) kilopascals respectively or (b) the quantity of heat, expressed in BTU/lbm, the quantity of heat produced by the complete combustion in dry air of one (1) pound mass of dry gas and the condensation of all water formed, with the initial and the final temperature and pressure being sixty (60) degrees Fahrenheit and an abolute pressure of fourteen decimal six nine six (14.696) pounds per square inch respectively.

“ICC” means the International Chamber of Commerce.

“ICC Court” means the Court of Arbitration of the International Chamber of Commerce.

“Independent Surveyor” means an independent surveyor appointed pursuant to Sub-Clause 8(6) to witness the unloading and the calculation of the Quantity Delivered.

“International Standards” means the international standards and practices applicable to the ownership, design, equipment, operation or maintenance of LNG vessels and liquefaction, storage facilities and unloading terminals established by:

(a)    The International Maritime Organisation (IMO), the Oil Companies International Marine Forum (OCIMF), or the Society of International Gas Tanker and Terminal Operators (SIGTTO); or

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(b)    Any other internationally recognised agency or organisation with whose standards and practices it is customary for reasonable and prudent owners or operators of such vessels or of such facilities and terminals to comply.

“Isle of Grain Terminal” means the LNG Receiving Facilities known as the Isle of Grain LNG Terminal, located in at the Isle of Grain, Kent, England, where Buyer or Buyer’s Affiliates owns capacity rights, fully available for the berthing of LNG ships, the unloading, receiving and storing of LNG, and the regasification and send out of LNG, where Buyer or Buyer’s Affiliates have a terminal use agreement or other enforceable right of access and use.

“Joule” means the derived “SI unit of quantity of heat J” as defined in “ISO 1000 SI units and recommendations for the use of their multiples and of certain other units”.

“kWh” means a quantity of energy equal to three decimal six million (3.6 x 10⁶) Joules.

“Laytime” has the meaning set forth in Clause 7.

“LNG” means liquefied natural gas, complying with the specifications set out in Sub-Clause 5(1), being a mixture of hydrocarbons produced at Seller’s Facilities.

“LNG Capacity” means, with respect to a Specific Order, the LNG shipping gross capacity of the LNG Ship, expressed in cubic meters, as stated in that Specific Order.

“LNG Receiving Facilities” means the facilities at the Discharge Port for arrival and berthing of LNG Ships and the receipt, storage and regasification of LNG.

“LNG Ship” means, with respect to a Specific Order, the vessel designed, constructed, equipped and maintained to load, carry and deliver LNG, nominated in that Specific Order and used by Seller pursuant to this Agreement.

“Loading Port” means, with respect to a Specific Order, the port where the LNG shall be loaded, as stated in that Specific Order.

“MARPOL” means the IMO’s International Convention for the Prevention of Pollution from Ships 1973, as modified by the Protocol of 1978 relating thereto (the “MARPOL 73-78 Convention”), and as supplemented by amendments to the MARPOL 73-78 Convention entering into force from time to time.

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“MJ” means one million (1,000,000) Joules.

“MMBtu” means one million (1,000,000) Btu.

“MWh” means one thousand (1000) kWh.

“Natural Gas” means a combustible mixture of hydrocarbon gases with or without inert and/or impurities of which the major component shall be methane and which is in the gaseous phase at a pressure of one hundred one thousand, three hundred twenty-five (101,325) Pascals and at the temperature of zero degree Celsius (0°C).

“Net Proceeds” has the meaning set forth in Sub-Clause 4(3).

“Nominal Quantity” means, with respect to a given cargo of LNG delivered under this Agreement, the nominal quantity specified in the Specific Order applicable to such cargo.

“Normal Cubic Meter” or “Nm^3” of Natural Gas means the quantity of dry real Natural Gas which at zero (0) degree Celsius and at an absolute pressure of one decimal zero one three two five (1.01325) bar and when free of water vapor occupies the volume of one (1) cubic meter.

“Notice of Arrival” or “NOA” means a notice given, substantially in the form set forth in Schedule C, by the LNG Ship, as defined in Sub-Clause 7.1.1.

“Notice of Readiness” means a notice given, substantially in the form set forth in Schedule D, by the LNG Ship to the operator of the LNG Receiving Facilities as defined in Sub-Clause 7(1.1) (or 7(2.2) if the Discharge Port is at Isle of Grain Terminal or at the US LNG Terminals).

“Party” means either Buyer or Seller.

“Payee” has the meaning set forth in Sub-Clause 10(4).

“Payor” has the meaning set forth in Sub-Clause 10(4).

“Person” includes any natural person, corporation, company, partnership (general or limited), limited liability company, business trust, governmental authority or other entity or association.

“PBS” means the customary pilot boarding station or the customary alternative waiting area as determined by the proper port authorities at the Discharge Port.

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“Quantity Delivered” means the quantity of energy expressed in MMBtu contained in a cargo of LNG unloaded under a Specific Order as per the EX-SHIP Certificate of Volume on Unloading and the EX-SHIP Certificate of Quality on Unloading.

“Reasonable and Prudent Operator” refers to the standard of care to be exercised by a Party in performing its obligations hereunder and means the degree of diligence, prudence and foresight reasonably and ordinarily exercised by an experienced operator engaged in the same line of business under the same or similar circumstances and conditions having due consideration to the interests of the other Party.

“Rules” means the Rules of Arbitration of the International Chamber of Commerce.

“Seller’s Facilities” means the liquefaction plant, storage and loading facilities at the Loading Port.

“Specific Order” means the agreement entered into, from time to time, by the Parties substantially in the form set forth in Schedule A to this Agreement, such document being a confirmation of additional terms and conditions applicable to the sale and purchase of a specific quantity of LNG.

“Specifications” has the meaning set forth in Sub-Clause 5(1).

“SOLAS” means the International Convention for the Safety of Life at Sea, 1974, and the related Protocol of 1978, both as supplemented by amendments entering into force from time to time.

“Standard Cubic Feet” or “Scf” means, in relation to gas, the quantity of dry real gas, at a temperature of sixty (60) degrees Fahrenheit and an abolute pressure of fourteen decimal six nine six (14.696) pounds per square inch respectively.

“Standard Cubic Metre” or “Sm³” means, in relation to gas, the quantity of dry real gas, at a temperature of fifteen (15) degree Celsius and a pressure of one hundred one decimal three two five (101.325) kilopascals absolute contained in a volume of one (1) cubic metre.

“STCW” means the International Convention on Standards of Training, Certification and Watchkeeping for Seafarers, 1978, as amended 1995.

“Taxes” has the meaning set forth in Sub-Clause 11(2).

“USD” or “US$” means the legal currency of the United States of America.

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	“US LNG Terminals” means the LNG Receiving Facilities known as the Sabine Pass LNG Terminal, located in Cameron Parish, Louisiana, and any other terminal in North America where Buyer or Buyer’s Affiliates owns capacity rights, fully available for the berthing of LNG ships, the unloading, receiving and storing of LNG, and the regasification and send out of LNG, where Buyer or Buyer’s Affiliates have a terminal use agreement or other enforceable right of access and use.
	“Wobbe Index Value” equals the superior calorific value on a volumetric basis at the following specified conditions (15 °C; 1.01325 bar) for the combustion and at (15 °C; 1.01325 bar) for volume divided by the square root of the relative density at the same specified metering conditions (ISO 6976: 1995).
1(2)	Except as otherwise defined or for deliveries into the United States where the United States customary units shall be used, units of measurements and then prefixes shall be based on the metric system in accordance with ISO 1000: 1992 or any later version “SI Units and recommendations for the use of their multiples and certain other units”.
1(3)	Unless otherwise provided in this Agreement, words denoting the singular shall have the corresponding meaning when used in the plural and vice-versa. References to any gender include all others if applicable in the context.
1(4)	The index and headings to Clauses are inserted for convenience of reference only and shall not affect the construction of this Agreement.
1(5)	If any specific provision of a Specific Order conflicts with the terms contained in this Master EX-SHIP LNG Sales Agreement, then the specific provision of the Specific Order shall prevail.
2.	SALE AND PURCHASE; SPECIFIC ORDERS
2(1)	This Agreement applies to the sale and purchase of LNG; provided, however, that neither Party shall have any obligations or liabilities with respect to the sale or purchase of a specific quantity of LNG unless and until both Parties have executed a Specific Order with respect to such specific quantity of LNG.
2(2)	In accordance with the terms of this Agreement, Seller agrees to sell and deliver LNG to Buyer and Buyer agrees to purchase, receive and pay Seller for the Quantity Delivered under a Specific Order or pay for the Nominal Quantity pursuant to Sub-Clause 4(3).

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2(3)	The LNG Ship shall be provided by Seller, as specified in the relevant Specific Order and at its expense, for the delivery of LNG pursuant to this Agreement. Except as otherwise agreed in the relevant Specific Order, LNG shall be sold in full and complete cargoes.
3.	QUANTITY
	The number of full cargoes of LNG to be sold and purchased under this Agreement shall be specified in the relevant Specific Order(s) executed by the Parties pursuant to this Agreement.
4.	DELIVERY SCHEDULE
4(1)	If the LNG Ship issues its Notice of Arrival at the PBS of the Discharge Port (or its Notice of Readiness in the case of Discharge Port being at the Isle of Grain Terminal or at the US LNG Terminals), during the Arrival Period specified in the Specific Order, (i) as between LNG cargoes being purchased or to be received by Buyer, Buyer shall ensure that the LNG Ship has the highest priority in berthing that is available to Buyer under its terminal use agreement (or any other applicable agreement giving Buyer capacity rights at the LNG Receiving Facilities) with the operator of the LNG Receiving Facilities, (ii) Seller shall deliver LNG to Buyer at the Delivery Point; and (iii) Buyer shall receive LNG at the LNG Receiving Facility in accordance with the usual procedures for such LNG Receiving Facility.
4(2)	In case the LNG Ship issues its Notice of Arrival (or Notice of Readiness if at the Isle of Grain Terminal or at the US LNG Terminals) before or after the Arrival Period but within forty-eight (48) hours of the Arrival Period, Buyer shall make all reasonable endeavours to berth the LNG Ship as soon as practicable following the issuance of the Notice of Arrival (or Notice of Readiness if at the Isle of Grain Terminal or at the US LNG Terminals).
4(3)	If Buyer fails, for any reason other than Force Majeure or Adverse Weather Conditions or the default of the Seller, to receive an LNG cargo in accordance with the provisions of this Agreement, Seller and Buyer shall use reasonable efforts to find a mutually and acceptable arrangement. In case the Seller and Buyer are unable to agree in good faith within a period of forty-eight (48) hours after the expiry of the Arrival Period, or such longer period as the Parties may agree to, on a date and time for berthing the LNG Ship and unloading the LNG cargo at the LNG Receiving Facilities, then the LNG Ship shall be entitled to depart from the Discharge Port and Seller shall be entitled to receive liquidated damages from Buyer (the “Deemed Delivery Amount”). The Deemed

9

	Delivery Amount shall be paid by Buyer in accordance with Clause 10 and shall be calculated as: (P x Q) where P is the Price as defined in the relevant Specific Order applicable to such cargo, and where Q is the Nominal Quantity specified in the Specific Order.
	Payment of the Deemed Delivery Amount, in addition to Demurrage, if any, shall be Seller’s sole and exclusive remedy in damages for the failure by Buyer to receive LNG. In the event Seller is able to complete a sale of the LNG cargo that Buyer failed to receive to a third party, Buyer shall be entitled to receive the net proceeds of such sale realized by Seller from such third party (being the total proceeds received from the sale to such third party less all fees, commissions, duties, expenses and costs of sale, and other LNG Ship expenses (including but not limited to bunkering and hire) over and above those costs which would have been incurred in transporting the cargo to LNG Receiving Facilities (the “Net Proceeds”); provided, however, that if the Net Proceeds exceed the total amount paid or payable by Buyer in respect of such cargo, the difference between such Net Proceeds and the amount paid or payable by Buyer shall be retained by Seller for its own account.
4(4)	If for any reason other than Force Majeure or Adverse Weather Conditions or Buyer’s default, Seller is unable or fails to deliver an LNG cargo to Buyer in accordance with the provisions of this Agreement, Seller and Buyer shall use reasonable efforts to find a mutually and acceptable arrangement. In case the Seller and Buyer are unable to agree in good faith within a period of forty-eight (48) hours after the expiry of the Arrival Period, or such longer period as the Parties may agree to, on a date and time for berthing the LNG Ship and unloading the LNG cargo at the LNG Receiving Facilities, then Seller shall pay to Buyer, in accordance with Clause 10, damages (the “Cargo Underdelivery Amount”) as defined in the Specific Order.
	Payment of the Cargo Underdelivery Amount shall be Buyer’s sole and exclusive remedy for the failure by Seller to deliver any cargo and Seller shall not be obliged to sell or deliver any replacement cargo to Buyer.
5.	QUALITY
5(1)	The LNG sold hereunder shall, at the time of unloading at the Discharge Port, comply with the quality specifications (“Specifications”) set forth in the Specific Order applicable to such cargo of LNG.
5(2)	After completion of loading, if, in the opinion of Seller, the quality of the LNG may fail to comply with the Specifications, Seller shall notify Buyer of the expected quality of the LNG (at the time of unloading) as soon as reasonably practicable. Buyer shall provide Seller, promptly after the reception of the above

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	mentioned notification, with a reasonable and documented estimate of the costs to treat the LNG (if such treatment is possible) and the costs to remedy any direct damage to the LNG Receiving Facilities arising from the LNG being unloaded there (“Estimated Treating Costs”). If Seller accepts to pay such Estimated Treating Costs, then, subject to the agreement of the operator of the LNG Receiving Facilities, the Buyer shall have the obligation to accept the cargo subject to the cargo being treated as agreed; payment of actual documented treating costs up to the Estimated Treating Costs, shall constitute Buyer’s sole and exclusive remedy for any damages arising from the LNG not complying with the Specifications. If after completion of unloading, such cargo was indeed to comply with the Specifications, Seller shall be relieved of its obligation to pay Estimated Treating Costs. If it is not possible to treat the LNG or the Seller does not accept to pay the Estimated Treating Costs then the Buyer shall have the right to reject that cargo and in such case the Seller shall pay the Buyer the Cargo Underdelivery Amount.
5(3)	In the event that it is discovered at the time of unloading, excluding the situation described in 5(2), that the quality of LNG as per EX-SHIP Certificate of Quality on Unloading materially fails to comply with the Specifications applicable to such cargo if ascertained before completion of unloading or the issuance of the Ex-Ship Certificate of Quality on Unloading, Seller agrees to reimburse Buyer for any reasonable actual documented direct costs incurred by Buyer in treating such LNG received at the LNG Receiving Facilities and in remedying any direct damage to the LNG Receiving Facilities (including any amount for which the Buyer may be liable to the operator of the LNG Receiving Facilities) arising from the LNG being unloaded there, by reason of it being out of Specifications.
	In the above circumstances the Buyer shall be obliged to accept the LNG still to be delivered unless the operator of the LNG Receiving Facilities has refused to accept the LNG by reason of its being out of the Specifications, after Buyer having duly used reasonable efforts to cause the operator of the LNG Receiving Facilities to accept each cargo of LNG that can be processed at the LNG Receiving Facilities, in which case Buyer shall have the right to reject the remaining LNG, subject to the LNG Ship can operate and leave the berth safely.
5(4)	Buyer shall promptly invoice Seller for amounts due under Sub-Clause 5(2). Seller shall pay Buyer in immediately available funds within ten (10) Business Days after receipt of such invoice.
	Any payments paid by Seller and due under Sub-Clause 5(2) shall be Buyer’s sole and exclusive remedy for Seller’s failure to comply with the Specifications.

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6.	SHIPPING AND LNG RECEIVING FACILITIES
6(1)	Seller shall, during the term of this Agreement, cause the LNG Ship to be provided, maintained and operated in good working order, such that Seller is able to fulfil its obligations under this Agreement and shall give Buyer a reasonable opportunity to vet and inspect the LNG Ship at Buyer’s sole risk and costs. Seller shall cause the LNG Ship to be maintained, operated, equipped and manned at all times throughout the period of supply of LNG pursuant to a Specific Order so as to be able to meet all applicable laws, requirements of the country of LNG Ship registry and of the authorities of the Discharge Port (including the International Ship and Port Facilities Security Code and in the US, the Maritime Transportation Security Act of 2002), the requirements of LNG Receiving Facilities (applicable to all users of such facility on a non-discriminatory basis) and maritime regulations of the International Maritime Organisation (IMO) and STCW (or other applicable International Standards as may be issued in replacement thereof) required in the countries in which the LNG Ship will call, and the industry recommendations and guidelines of the Oil Companies International Marine Forum (OCIMF) and the Society of International Gas Tanker & Terminal Operators (SIGTTO). In that respect Seller shall ensure that the LNG Ship (i) complies in all respects with the standards established by SOLAS, the International Management Code for the Safe Operation of Ships and for Pollution Prevention (ISM Code), the International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (IGC Code), (ii) has discharge and emission levels within MARPOL guidelines and (iii) is designed and constructed in accordance with the rules and regulations of, and maintained in class with a member of the International Association of Classification Societies (IACS).
6(2)	Buyer shall, at all times throughout the period of supply of LNG pursuant to a Specific Order, cause the LNG Receiving Facilities to be maintained and operated in good working order and in a safe and efficient manner and shall use reasonable endeavours to give Seller an opportunity to inspect at its sole risk and cost, the LNG Receiving Facilities.
	The LNG Receiving Facilities shall include a line for vaporized gas, so that the unloading can be undertaken in a safe manner. Seller and Buyer shall agree on the conditions as to quantity, rate, pressure and temperature with regard to the capability of the relevant facilities to ensure safe unloading, as the case may be.
6(3)	Prior to the execution of any Specific Order, Buyer shall provide Seller with the specifications of the LNG Receiving Facilities, Seller shall provide Buyer with the specification of the LNG Ship and Buyer and Seller shall confirm that the LNG Ship is compatible with the LNG Receiving Facilities. The Parties will provide each other reasonable assistance in making such determination. Execution of the

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	relevant Specific Order shall constitute acknowledgement by Buyer and Seller that, as of the date of execution of such Specific Order, the LNG Ship and the LNG Receiving Facilities are compatible with each other. Following such acknowledgement, neither Party shall take any action that would render the LNG Ship and the LNG Receiving Facilities incompatible with each other and, subject to any applicable laws, regulations or governmental or port authority directives or orders, Seller shall not permit or make any modification to the LNG Ship which could affect the compatibility with the LNG Receiving Facilities without Buyer’s prior written consent, such consent not to be unreasonably withheld taking into account the compatibility of the LNG Receiving Facilities with the LNG Ship, and Buyer shall not permit or make any modification to the LNG Receiving Facilities which could affect the compatibility with the LNG Ship following such acknowledgement.
6(4)	If the approved LNG Ship and LNG Receiving Facilities should prove not to be compatible, the Parties shall consult and co-operate with a view to agreeing upon a course of action which will permit this Agreement and the applicable Specific Order to be performed.
6(5)	Seller may, subject to prior consent of Buyer, which shall not be unreasonably withheld provided the Buyer has been given a reasonable opportunity to inspect and vet the ship and the ship meets its vetting requirements, substitute another LNG Ship other than the one named in the Specific Order, provided that such LNG Ship is compatible with the Discharge Port and the LNG Receiving Facilities.
6(6)	Subject to Clauses 7.4 and 11, all LNG Ship charges at the Discharge Port shall be paid by Seller. This includes the use in any manner of tugs, pilots, escort vessels or other support vessels used in connection with the safe berthing of the LNG Ship, including such assistance or use required by the port authorities or regulations or usual practice in the Discharge Port and the LNG Receiving Facilities (applicable to all users of such facility on a non-discriminatory basis). All such assistance and services shall be used by the Seller at its sole risks.
	In addition, in case Buyer should request any further specific assistance, then such expenses shall be borne by Buyer.
7.	SHIP MOVEMENTS AND UNLOADING
7(1)	General
7(1.1)	Seller shall ensure that the LNG Ship gives Buyer and the operator of the LNG Receiving Facilities the following notices mentioning its ETA at the PBS of the Discharge Port :
	(a)    on departure from the port where its last call took place;

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	(b)    seven (7) Days prior to the ETA;
	(c)    seventy-two (72), forty-eight (48) and twenty-four (24) hours prior to the ETA;
	(d)    the Notice of Arrival (NOA) shall be sent when the LNG Ship has arrived at the PBS; and
	(e)    the Notice of Readiness shall be sent after:
	(i) the LNG Ship is safely moored alongside the berth,
	(ii) the measurement on board the LNG Ship and the connection of the loading arms has taken place, and
	(iii) the LNG ship has obtained all authorizations necessary to discharge such cargo of LNG.
	The notices required under paragraphs (b) and (c) hereunder shall be adapted to comply with the requirements of the Discharge Port authorities or the operators of the LNG Receiving Facilities as are notified to Seller by Buyer, prior to the execution of a Specific Order.
7(1.2)	The time used in unloading the LNG Ship (“Laytime”) shall begin to count at the earlier of:
	(i)     Six hours after issuing the Notice of Arrival if the LNG Ship issues such notice during the Arrival Period or less than six hours prior to it,
	(ii)    At the time of the beginning of the Arrival Period, if the LNG Ship issues its NOA, at least six hours before the commencement of the Arrival Period,
	(iii)  when the LNG Ship is safely moored and ready to discharge.
	provided that:
	a)      if the Discharge Port has night-time or tidal restrictions and the LNG Ship has issued its NOA at a time of Day which does not permit the LNG Ship to commence its voyage from the PBS to the Delivery Point under the applicable rules or regulations applying to the Discharge Port at that time, then the LNG Ship shall be deemed to have issued its NOA at the time when the Discharge Port opens or permits the LNG Ship to commence its voyage from the PBS to the Delivery Point
	b)      if the LNG Ship issues its NOA after the Arrival Period, time shall begin to count on the commencement of unloading of the LNG Ship; and
	Laytime shall be deemed to be completed and time shall cease to count when the LNG Ship passes the PBS outbound.
	The Allowed Laytime under this Sub-Clause 7(1) shall be as specified in the relevant Specific Order subject to any applicable extension. Allowed Laytime shall be extended by the time during which proceeding from the PBS, anchorage, berthing, unloading or proceeding to the PBS outbound is delayed or hindered by:
	(i) events of Force Majeure,

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	(ii) acts or omissions of Seller,
	(iii) reasons attributable to the LNG Ship or her owner, operator or manager, or
	(iv) reasons attributable to any employee or agent of any of the foregoing Persons described in Sub-Clauses (ii) and (iii) above.
7(2)	Discharge Port at the Isle of Grain Terminal or at the US LNG Terminals
7(2.1)	The Seller shall give notice to the operator of the LNG Receiving Facilities, as soon as reasonably practicable after the LNG Ship’s departure from the Loading Port, setting out the following:
	(i)     the name of the LNG Ship;
	(ii)    the ETA of the LNG Ship;
	(iii)  details of any operational deficiencies in the LNG Ship that may affect its operations in the Discharge Port or at the LNG Receiving Facilities;
	(iv)   the quality, density and volume of LNG loaded;
	(v)    the estimated quality, density and volume of LNG to be unloaded; and
	(vi)   the estimated temperature of the LNG and temperature and pressure of the vapour in the tanks of the LNG Ship upon arrival at the LNG Receiving Facilities;
	and the Seller shall promptly inform the Buyer and the operator of the LNG Receiving Facilities of any change in the foregoing.
	The Seller shall give notice to the Buyer and to the operator of the LNG Receiving Facilities, and shall update the latest such notice in the event of a change of ETA of more than a specified period, as follows:

Time when notice to be given	Content of notice	Change of ETA requiring updated notice
96 hours before current ETA	Confirmed or updated ETA	6 hours
72 hours before current ETA	Confirmed or updated ETA	6 hours
48 hours before current ETA	Confirmed or updated ETA	6 hours
24 hours before current ETA	Confirmed or updated ETA	2 hours
12 hours before current ETA	Confirmed or updated ETA	1 hour
5 hours before ETA	Confirmed or updated ETA	Any change

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7(2.2)	When the LNG Ship has arrived at the PBS or customary anchorage at the Discharge Port, has taken on board the pilot, has received all necessary port clearances and is ready and able to proceed to berth and unload LNG, the Seller shall give a Notice of Readiness to the operator of the LNG Receiving Facilities, provided, however, that
	(i)     in the event the LNG Ship arrives at the Discharge Port and gives Notice of Readiness prior to the Arrival Period, the Notice of Readiness shall be deemed effective at the earlier of:
	(a)    on the first hour of the Arrival Period; and
	(b)    the time at which unloading commences;
	(ii)    in the event the LNG Ship gives Notice of Readiness after the Arrival Period, the Notice of Readiness shall be deemed effective when and if the operator of the LNG Receiving Facilities notifies the Seller that the LNG Ship may proceed to berth.
7(2.3)	The Allowed Laytime shall be as specified in the Specific Order, subject to any applicable extension.
	Allowed Laytime shall be extended by any period of delay which is caused by one or more of the following:
	(i)     reasons attributable to the Seller, the LNG Ship or her master, crew, owner or operator; or any of the agents or contractors of any of the foregoing (such as tugs, line boats, service boats, fire boats or other escort vessels);
	(ii)    events of Force Majeure;
	(iii)  the compliance by the LNG Ship with Discharge Port regulations;
	(iv)   Adverse Weather Conditions;
	Laytime used shall begin to count upon Notice of Readiness being given or (if later) becoming effective in accordance with Sub-Clause 7(2.2) and shall continue to run until the time at which the last unloading arm is disconnected and the LNG Ship is cleared for departure and is able to depart.
	If any problem occurs or is foreseen to occur so as to cause delay to the LNG Ship in berthing, unloading or departing, the Seller, the Buyer and the operator of the LNG Receiving Facilities shall discuss it in good faith and use their reasonable endeavours to minimise or to avoid the delay, and at the same time shall co-operate with each other to find counter measures to minimise or to avoid the occurrence of any similar delay in the future.
7(3)	Upon the proper issuance by the LNG Ship of the Notice of Arrival (or Notice of Readiness in the case of unloading at the Isle of Grain Terminal or at

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	the US LNG Terminals), and subject to the provisions of Clause 4, (i) Seller shall cause the LNG Ship to be berthed at the berth designated by the operator of the LNG Receiving Facilities, and (ii) Buyer shall co-operate and or cause the operator of the LNG Receiving Facilities to cooperate, in the LNG Ship being so berthed. If requested by Seller, Buyer shall endeavour to provide assistance to Seller, at Seller’s cost, in clearing the formalities required by the relevant authorities.
7(4)	Buyer shall exercise due diligence in arranging for the unloading of the LNG Ship at a safe berth, which Buyer shall provide free of charge to Seller. A safe berth being one which the LNG Ship can safely reach and leave and at which it can lie and unload, always safely afloat and safety moored alongside. The foregoing Sub-Clause shall not be construed to relieve the master of the LNG Ship from his obligations in respect of the safety of the LNG Ship and its crew.
7(5)	Buyer shall commence unloading or cause it to be commenced as soon as practicable after the completion of berthing and shall complete unloading or cause it to be completed safely, effectively and expeditiously. Seller shall cooperate and cause the operator or manager of the LNG Ship to cooperate in such unloading. Seller shall be entitled to retain the volume of LNG heel specified in the Specific Order.
7(6)	Seller shall cause the LNG Ship to depart safely and expeditiously from the berth as soon as practicable after the completion of unloading, and thereafter to proceed expeditiously to pass the PBS outbound.
	Buyer shall co-operate, in a safe and expeditious departure of the LNG Ship from the berth.
7(7)	If any problem occurs or is foreseen to occur which will or may cause delay to the LNG Ship in berthing or unloading or departing, Buyer and Seller shall discuss it in good faith and use reasonable efforts to minimize or to avoid the delay.
7(8)	If Laytime used exceeds the Allowed Laytime as specified Sub-Clause 7(1) or 7(2) as the case may be, Buyer shall pay Demurrage to Seller at the daily rate specified in the Specific Order pro rata for every day, or part thereof.
8.	MEASUREMENT, SAMPLING AND TESTING
8(1)	Promptly after the completion of each loading of an LNG Ship at the Loading Port for a delivery under this Agreement, Seller shall notify Buyer, for operational purposes, by facsimile, of the quantity of LNG loaded, including its Gross Heating Value (Volume Based), hydrocarbon composition, density and trace levels.

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8(2)	The volume in cubic meters of LNG of each shipment shall be measured at the Delivery Point by or on behalf of Seller following the procedures described in Schedule B. Seller shall, within twenty-four (24) hours following the completion of unloading, notify Buyer of the volume of LNG unloaded (the “EX-SHIP Certificate of Volume on Unloading”).
8(3)	The Gross Heating Value (Volume Based) of the LNG in each cargo shall be determined on unloading by the operator of the LNG Receiving Facilities of the Discharge Port by the method described in Schedule B. Buyer shall, within forty-eight (48) hours following the completion of unloading, notify Seller of the quality (the “EX-SHIP Certificate of Quality on Unloading”), or cause it to be notified to Seller. Buyer shall collect two (2) spot samples and retain samples for a period of at least thirty (30) Days after Buyer’s notification.
8(4)	Buyer shall calculate the Quantity Delivered or cause it to be calculated, using the results derived from the procedures specified in Sub-Clauses 8(2) and 8(3), and the method described in Schedule B. Buyer shall promptly notify such Quantity Delivered or cause it to be notified to the Seller. Such notification shall include all data and documents necessary to support the calculation of the Quantity Delivered.
8(5)	Either Party may have at its sole risk and cost a representative present to witness the measurement, sampling and testing of LNG.
8(6)	The Parties shall appoint a mutually acceptable Independent Surveyor to witness the unloading of each cargo of LNG and the calculation of the Quantity Delivered. Such Independent Surveyor shall be qualified by education, experience and training to monitor such LNG activity. The cost to engage such Independent Surveyor shall be equally shared by Seller and Buyer.
8(7)	If, as to the results obtained pursuant to Sub-Clauses 8(2), 8(3) or 8(4), either Party notifies a disagreement to the other Party, then the Parties shall jointly appoint an Expert. Such person shall be qualified by education, experience and training to determine the matter in dispute. Such person shall be required to fully disclose any interest or duty that conflicts or may conflict with his function under such appointment. Upon such disclosure, the Parties may appoint such person as an Expert only upon the prior written consent of both Parties in light of such conflicting interest or duty.
	If, within twenty-one (21) Days of receipt of the notification of disagreement, the Parties fail to jointly appoint an Expert, either Party shall have the right to request the International Chamber of Commerce’s International Center for Expertise to

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	appoint such Expert. Such Expert shall act as an independent expert and not as an arbitrator and his findings of fact, which shall be rendered within ninety (90) Days of his appointment, shall be final and binding on the Parties save in case of fraud or manifest error or the failure by the Expert to disclose any relevant interest or duty which conflicts or may conflict with his appointment. The cost to engage such Expert shall be shared equally by Seller and Buyer. At the end of the process, the losing Party – if any – shall reimburse the other Party for the total amounts it has paid.
	If a Party fails to comply with the decision of the Expert within thirty (30) Days of receipt thereof, then on the request of any Party, the disagreement shall be submitted to binding arbitration in accordance with Sub-Clause 15(2). The findings of fact of the Expert shall be binding on the arbitral tribunal except in the case of fraud or manifest error or the failure by the Expert to disclose any relevant interest or duty which conflicts or may conflict with his appointment. The full cost of the arbitration (including the reasonable attorneys’ fees of both Parties) shall be borne by the Party that fails to comply with the decision of the Expert, unless there is a finding of fraud or manifest error or the failure by the Expert to disclose any relevant interest or duty which conflicts or may conflict with his appointment.
	If the Expert does not render a decision within ninety (90) Days of his appointment, at the request of any Party prior to the issuance of such decision, a new Expert shall be appointed under the provisions of this Agreement and upon acceptance of appointment by such new Expert, the appointment of the previous Expert shall cease.
9.	TRANSFER OF TITLE AND RISK
	The title, the risk of loss and damage and any liabilities resulting from the LNG sold and purchased under this Agreement shall remain with Seller until transferred to Buyer upon delivery of the LNG by Seller at the Delivery Point.
	The title, the risk of loss and damage and any liability resulting from Natural Gas vapour returned to the LNG Ship during unloading of LNG shall pass from Buyer to Seller as it passes the point at which the outlet flange of the vapour return line of the LNG Ship connects with the inlet flange of the vapour return line of the LNG Receiving Facilities.
10.	PRICE AND PAYMENT
10(1)	The price (“Price”) of LNG sold under this Agreement shall be specified in the relevant Specific Order.

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10(2)	The amount payable by Buyer to Seller for each cargo of LNG sold under this Agreement shall be calculated by multiplying the Quantity Delivered as notified pursuant to Sub-Clause 8(4) by the Price specified in Sub-Clause 10(1), subtracting from the result the amount, if any, due from Seller to Buyer under Sub-Clause 5(2).
	The amount payable shall be increased by the Demurrage due from Buyer to Seller, if any, as specified in Sub-Clause 7(8).
10(3)	Prior to the arrival of the LNG Ship at the Discharge Port, Seller or its representative shall furnish to Buyer any and all other documents concerning the cargo, as may reasonably be requested by Buyer, for the purposes of customs clearance at the Discharge Port.
	Promptly following the completion of unloading or if Buyer fails to take delivery pursuant to Sub-Clause 4(3), Seller shall send to Buyer an invoice showing the amount payable calculated pursuant to Sub-Clause 10(2) together with the relevant supporting documents mentioned in Sub-Clause 8(4).
	If Seller becomes obligated to pay Buyer any amount under Sub-Clause 4(4), Buyer shall send to Seller an invoice showing the amount payable pursuant to Sub-Clause 4(4).
	If the LNG has a European Union origin, Seller shall provide Buyer a document certified by the customs of the country in which such LNG has been imported, in order to testify that the Quantity Delivered has a European Union origin.
10(4)	Upon receipt of an invoice pursuant to Sub-Clause 10(3), the Party receiving such invoice (the “Payor”) shall pay the amount payable under such invoice within twenty (20) Business Days from the date of receipt of such original invoice sent pursuant to Sub-Clause 10(3). Payment shall be made by wire transfer in the currency agreed upon in the Specific Order, free of all charges and without asserting any set-off or counter-claim or making any deduction into a bank account nominated by the Party submitting such invoice (the “Payee”).
10(5)	If, by the operation of any provision of Sub-Clause 8(7), the Quantity Delivered is not immediately determined as final, then Seller shall provide Buyer with a preliminary invoice as soon as practicable after the completion of unloading. Such preliminary invoice shall be issued showing the provisional Quantity Delivered, as estimated in good faith by the Seller, and/or the provisional price. Buyer shall pay such preliminary invoice in accordance with Sub-Clause 10(4). After final determination of the Quantity Delivered, and/or after the determination of the final LNG price, which shall not be unreasonably delayed, Seller shall promptly provide Buyer with a final invoice and the

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	appropriate adjustment payment (including interest as calculated under Sub-Clause 10(7)) shall be made by Buyer or Seller (as applicable) to the other within twenty (20) Business Days from the date of receipt of the final invoice by Buyer.
10(6)	In the event the Payor disputes an invoice, it shall nevertheless make provisional payment of one hundred percent (100%) of the total amount thereof and shall immediately notify the Payee of the reasons for such disagreement, except that in the case of an obvious or manifest error or fraud in computation, the Payor shall pay the correct amount after disregarding such error or fraud. An invoice may be contested by the Payor, or modified by the Payee, by written notice delivered to the other Party within a period of sixty (60) Days after such receipt or sending, as the case may be. If no such notice is served, such invoice shall be deemed correct and accepted by both Parties. Promptly after resolution of any Dispute as to an invoice pursuant to Sub-Clause 15(2), the amount of any overpayment or underpayment shall be paid by Seller or Buyer, as the case may be, to the other Party, together with interest thereon at the rate and conditions provided in Sub-Clause 10(7).
10(7)	If Buyer or Seller, as the case may be, fails to pay the other Party an amount due under any invoice or under the terms of this Agreement by the due date for payment, such non-paying Party shall pay interest thereon to the other Party for the period commencing on and including the next Day following the due date up to and including the Day when payment is made. Interest shall be calculated at the rate of two percents (2%) above:
	(a)    the Euribor as quoted on the date when payment was due or, in case the Euribor is not available on such date on the first following date when such rate is published, if payment has to be made in Euros; where Euribor means the rate of interest per annum published by the European Central Bank for deposits in Euros for a three (3) month period representing the Euros interbank offered rates for this currency.;
	(b)    the Libor as quoted on the date when payment was due or, in case the Libor is not available on such date on the first following date when such rate is published, if payment has to be made in USD; where Libor means the rate of interest per annum published by the British Bankers Association for deposits in USD for a three (3) month period.
	Interest shall be calculated on the basis of a three hundred sixty-five (365) Days per year and shall be paid on the date when payment of the amount due is made.
11.	TAXES AND CHARGES
11(1)	All Taxes (as defined in Sub-Clause 11(2) below) related to a sale transaction covered by this Agreement arising in the country where the LNG Receiving Facilities are located shall be paid or borne by Buyer. Buyer shall reimburse Seller for any such Taxes, which Seller is obliged to pay. All Taxes related to a transaction covered by this Agreement arising in the country of the Loading Port shall be paid or borne by Seller. Seller shall reimburse Buyer for any such Taxes, which Buyer is obliged to pay.

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11(2)	In this Clause, “Taxes” means all taxes (excluding any income tax), charges, royalties, duties or other imposts whatsoever levied by a government or duly constituted authority on the LNG sold, hereunder or on the Natural Gas from which it was derived or in respect of the act, right or privilege of producing, processing or selling that LNG or Natural Gas.
12.	PERMISSIONS AND APPROVALS
12(1)	Seller shall obtain or cause to be obtained all necessary permissions, authorizations, approvals and other requirements necessary to enable it to perform its obligations under this Agreement.
12(2)	Buyer shall obtain or cause to be obtained all necessary permissions, authorizations, approvals and other requirements necessary to enable it to perform its obligations under this Agreement.
12(3)	If all the permissions and approvals described in Sub-Clauses 12(1) and 12(2) are not obtained prior to the execution of a Specific Order, Seller and Buyer shall consult in good faith.
13.	FORCE MAJEURE
13(1)	A Party is not liable for a failure to fulfill an obligation under this Agreement (other than an obligation to pay money due) and is not in breach of this Agreement, if and to the extent to which fulfilment has been delayed, interfered with or prevented by Force Majeure, which shall be defined as any circumstance whatsoever that is beyond the reasonable control of the Party affected. The Party claiming Force Majeure shall give to the other Party, as soon as practicable after such Force Majeure occurs, notice of such Force Majeure (the “Force Majeure Notice”). Such Force Majeure Notice shall include in detail all information available about the circumstances, the relevant facts and consequences, and a statement of the steps and time believed necessary to remedy the Force Majeure situation, and shall reasonably allow access to its facilities affected by or relating to the Force Majeure for a site inspection if desired, at the expense and risk of the Party examining the site.
	In this Agreement, provided the aforementioned requirements are met (including the requirement that the Force Majeure event be beyond the reasonable control of the claiming Party), “Force Majeure” includes but is not limited to:
	(a)    acts of God, lightning, storm warnings, fog restrictions, earthquakes, fires, floods, shipwreck, navigational and maritime perils, explosions, acts of the public enemy, wars, civil and military disturbances, blockades, insurrections, riots, epidemics, quarantine restrictions;

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	(b)    the compliance by the Party affected with an act, order or demand of an international, national, port, transportation, local or other authority or agency or of any body or Person purporting to be or act for such an authority or agency;
	(c)    a strike or any other kind of labor dispute;
	(d)    in the case of Seller, any circumstances relating to the loading of the LNG Ship at the Loading Port and/or the Seller’s Facilities or relating to the transport of the LNG, and which affect the ability of Seller to deliver the LNG at the LNG Receiving Facilities; and
	(e)    in the case of Buyer, any circumstances, relating to the unloading of the LNG at the LNG Receiving Facilities or at the high pressure Natural Gas transmission pipeline directly connected to the LNG Receiving Facilities, which affect the ability of Buyer to receive and/or unload the LNG at the LNG Receiving Facilities.
	Each of paragraphs (a), (b), (c), (d) and (e) of this Sub-Clause 13(1) shall be read and construed independently.
13(2)	In case of a Force Majeure situation, any Party claiming Force Majeure shall use reasonable endeavors:
	(a)    to eliminate the circumstance of Force Majeure relied on to enable it to resume full performance of its obligations; and
	(b)    to minimize the effects of the circumstance of Force Majeure; provided, however, that (i) such Party claiming Force Majeure shall not be obliged to take any steps which would be beyond its control or would not be taken by a Reasonable and Prudent Operator and (ii) a strike or any other kind of labor dispute may be settled by the Party concerned at its absolute discretion.
13(3)	For the purpose of Sub-Clause 13(1), unless a circumstance is beyond the reasonable control of Seller or any or all of the following Persons who are in any way related to the circumstance, such circumstance shall be deemed to be within the reasonable control of Seller :
	(a)    the owner, operator, manager or charterer of the LNG Ship; and

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	(b)    an employee, contractor or agent of one or more of the foregoing Persons or the Seller.
13(4)	For the purpose of Sub-Clause 13(1), unless a circumstance is beyond the reasonable control of Buyer or any or all of the following Persons who are in any way related to the circumstance, such circumstance shall be deemed to be within the reasonable control of Buyer :
	(a)    the owner, operator or delegated operator of the LNG Receiving Facilities; and
	(b)    an employee, contractor or agent of one or more of the foregoing Persons or the Buyer.
13(5)	In the event that, as a result of any circumstance of Force Majeure, Seller is not able or shall not be able to issue or cause to be issued the Notice of Arrival (or Notice of Readiness in case of Discharge Port being at the Isle of Grain Terminal or at the US LNG Terminals) during the Arrival Period or Buyer is not able or shall not be able to receive and unload a cargo pursuant to a Specific Order, the Parties shall use reasonable efforts to cause the delivery of and acceptance of such cargo following the Arrival Period; provided, however, if notwithstanding such efforts, the Parties are unable to agree within ten (10) Days following the end of the Arrival Period, then either Party shall be entitled (upon notice hereunder) to terminate the Specific Order concerned by such circumstance of Force Majeure without any obligations or liability of either Party hereto.
14.	LIABILITIES
14(1)	Except in the case of fraud, intentional act or omission or gross negligence, or where otherwise specified in this Agreement (if any) (a) liabilities of either Party to the other under this Agreement are limited to direct damages, losses, costs and expenses actually incurred by the affected Party and (b) neither Party (including its Affiliates) shall be liable to the other Party under this Agreement in contract, tort (including negligence) or otherwise howsoever, for or in respect of any special, indirect or consequential loss or damage, including any loss of income or profits as a result of any act or omission in the course of or in connection with the performance of this Agreement.
14(2)	Buyer shall be responsible for, and shall defend, indemnify and hold harmless Seller and its shareholders, partners, officers, directors, employees, representatives and agents, from and against, any and all losses, claims, costs and expenses arising with respect to any injury to or death of people or loss or damage

24

	to property of third parties arising directly from Buyer’s negligence, gross negligence or willful misconduct under this Agreement or from the LNG after custody thereof passes to Buyer at the Delivery Point.
14(3)	Seller shall be responsible for, and shall defend, indemnify and hold harmless Buyer and its shareholders, partners, officers, directors, employees, representatives and agents, from and against, any and all losses, claims, costs and expenses arising with respect to any injury to or death of people or loss or damage to property of third parties arising directly from Seller’s negligence, gross negligence or willful misconduct under this Agreement or from the LNG prior to custody thereof passing to Buyer at the Delivery Point.
14(4)	If either Party becomes aware of any matter in respect of which it is or may be entitled to be indemnified concerning this Agreement it shall promptly notify the indemnifying Party of such matter. If any action or claim has been brought against the indemnified Party by a third party in respect of such matter, the indemnifying Party shall be entitled at its expense to assume the defence of such action or claim in place of the indemnified Party using legal advisers approved by the indemnified Party (such approval not to be unreasonably withheld or delayed). The indemnified Party shall (subject to being indemnified to its reasonable satisfaction by the indemnifying Party against all actual direct and documented costs and expenses of so doing) take such action as the indemnifying Party may reasonably request in defending such action or claim.
15.	GOVERNING LAW AND ARBITRATION
15(1)	This Agreement is governed by and shall be construed in accordance with the laws of England and Wales.
15(2)	Except for a disagreement pursuant to Sub-Clauses 8(2), 8(3) or 8(4) which shall be governed by Sub-Clause 8(7), any dispute, controversy or claim arising out of or relating to this Agreement, or the breach, termination or invalidity thereof (the “Dispute”), which cannot be resolved by discussion in good faith between the Parties within sixty (60) Days from the receipt by a Party of notice of such Dispute shall be finally settled by arbitration in accordance with the Rules in force on the Execution Date. The number of arbitrators shall be three, one appointed by Buyer and one by Seller pursuant to the Rules, and the third appointed by the first two arbitrators within fifteen (15) Days after their confirmation by the ICC Court. If either Party fails to appoint an arbitrator or the two arbitrators appointed by the Parties fail to agree on the choice of the third arbitrator, the appointing authority is the chairperson or his equivalent of the ICC. The place of arbitration shall be Geneva, Switzerland. Any award shall be final

25

	and binding upon the Parties, and judgment upon the award rendered by the arbitrators may be entered in any court having jurisdiction (as per the New York Convention of 1958 on Recognition and Enforcement of foreign arbitral awards). The arbitration proceedings shall be conducted and the award shall be rendered in the English language. The prevailing Party shall be entitled to recover from the other Party the prevailing Party’s reasonable attorneys’ fees and expert witness’ fees incurred in connection with the arbitration.
16.	SAFETY
16(1)	Seller and Buyer recognize the importance of securing and maintaining safety in all matters contemplated in this Agreement including the operation of facilities (for Buyer) and the transportation of LNG (for Seller). The Parties shall maintain high standards of safety in accordance with the generally accepted standards prevailing in the LNG industry.
16(2)	Seller and Buyer shall use reasonable efforts to ensure that their respective employees, agents, contractors and suppliers have due regard to safety and abide by all applicable laws and regulations while they are performing works and services within and around the area of the LNG Receiving Facilities and onboard the LNG Ship, as the case may be.
17.	TERM
	This Agreement shall be in force for a primary term extending from the Execution Date through the last Day of the Option Period as defined in the GDF Transatlantic Option Agreement between the Parties dated of even date herewith. Thereafter, this Agreement shall remain in force unless and until a Party terminates the Agreement by thirty (30) Days prior written notice to the other Party and the other Party receives such written notice, provided that the obligations of the Parties as per any Specific Order agreed to prior to issuance of the notice of termination have to be performed before the effective termination of the Agreement.
18.	GENERAL
18(1)	Unless otherwise agreed, all notices to be given under this Agreement by one Party to the other are sufficiently given if in English, in writing and either delivered in person or sent by prepaid airmail or facsimile to the other Party at its address as it is specified in this Sub-Clause 18(1). Except for notifications pursuant to Sub-Clauses 7(1.1), 7(2.1), 7(2.2), 8(2) and 8(3), a notice given by facsimile shall be subsequently confirmed by letter, unless otherwise agreed, but without prejudice to the validity of the original notice.

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	•     Cheniere Marketing, Inc.
	700 Milam St., Suite 800
	Houston, Texas 77002
	U.S.A.
	Attn.: Contract Administration
	Fax:
	Telephone
	•     Gaz de France International Trading S.A.S.
	- For any notice concerning Payment :
	Post:	GAZ DE FRANCE INTERNATIONAL TRADING
		Colisée IV – 14 rue Fructidor
		75017 Paris, France
	Fax:	+ 33 1 41 66 06 06
	Attention:	LNG Back Office
	- For any other notice :
	Post:	GAZ DE FRANCE INTERNATIONAL TRADING
		Colisée IV – 14 rue Fructidor
		75017 Paris, France
	Fax:	+33 1 41 66 02 97 / +33 1 41 66 01 29
	Attention:	Manager – Operations
		and Assistant Vice President – LNG
	Each Party is entitled to modify its above-mentioned contact addresses, numbers and names upon two (2) Days prior notice served to the other Party by registered mail.
18(2)	The Parties agree to treat this Agreement and all information, whether written or oral, which is not known by or available to the public and which concerns the contents of this Agreement as strictly confidential (the “Confidential Information”). The Parties agree not to disclose any Confidential Information to any third party without the prior written consent of the other Party hereto, except for such information required to be disclosed by either Party to its employees, independent contractors, agents, professional advisers and Affiliates who have a need to know such information for performing under this Agreement, to any court

27

	or governmental authority requiring such, or to any other appropriate third party to the extent necessary to comply with any legal or governmental requirement (including the United States Securities and Exchange Commission) having or asserting jurisdiction over a Party or its Affiliates and having or asserting authority to require such disclosure in accordance with that authority, or pursuant to the rules of any recognized stock exchange or agency established in connection therewith. For disclosure by either Party of Confidential Information to the operators of the Loading Port, Discharge Port, LNG Receiving Facilities or LNG Ships to the extent necessary to comply with such Party’s obligations under this Agreement, such prior written consent of the other Party shall not be unreasonably withheld. Except in the case of such information already forming part of the public domain, such disclosing Party shall use all reasonable efforts to ensure that the third party receiving such Confidential Information maintains its confidentiality. This Sub-Clause shall remain in force for three (3) years after the termination of this Agreement. The Parties acknowledge that this Agreement will be filed with the United States Securities Exchange Commission.
18(3)	Neither Party may assign any of its rights and obligations under this Agreement without first obtaining the consent in writing of the other Party.
	Notwithstanding the above, a Party may assign its rights and obligations in respect of a transaction (as originated in a Specific Order) to an Affiliate or a financial institution (a bank or other financial entity having assets of at least one (1) Billion USD) to secure such Party’s indebtedness on notice to, but without the consent of, the other Party; provided, however, that in such circumstances until the consent of the other Party is obtained the assignor shall not be relieved of any obligations that such Affiliate fails to perform.
18(4)	In the event Buyer shall:
	(i)     make an assignment or any general arrangement for the benefit of creditors;
	(ii)    default in the payment of undisputed amounts due to Seller under this Agreement, which default is not remedied within ten (10) Days of written notice from Seller requiring such remedy under this Agreement;
	(iii)  file a petition or otherwise commence, authorize, or acquiesce in the commencement of an proceeding or cause under any bankruptcy or similar law for the protection of creditors or have such petition files or proceeding commenced against it;
	(iv)   otherwise become bankrupt or insolvent (however evidenced);
	(v)    be unable to pay its debts as they fall due; or
	(vi)   fail to give adequate security for or assurance of its ability to perform its further obligations under this Agreement within five (5) Days of a reasonable and substantiated request notified by Seller;

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	then, notwithstanding any provision to the contrary in this Agreement, Seller shall have the right to either suspend its obligations under this Agreement or terminate the Agreement forthwith on written notice, in addition to any and all other remedies, available hereunder or pursuant to law.
18(5)	[INTENTIONALLY LEFT BLANK]
18(6)	The failure of either Party at any time to require performance of any provision of this Agreement shall not affect its right to require subsequent performance pursuant to that provision, nor shall the waiver by either Party of any breach of any provision or this Agreement be deemed to be a waiver of any subsequent breach of such provision or a waiver of any other provision of this Agreement.
18(7)	This Agreement constitutes the entire agreement between the Parties on the subject matter of this Agreement and supersedes and replaces any provisions on that subject contained in any other agreement between the Parties, whether written or oral entered into by the Parties prior to the date of execution hereof, provided that nothing in this Agreement shall operate to limit or exclude any liability for fraud.
18(8)	This Agreement may not be amended except by an instrument in writing signed by the Parties or by a Specific Order.
18(9)	Subject to the rights that may accrue to any successor or permitted assigns of the Parties, no provision of this Agreement shall be construed as creating any rights enforceable by a third party and all third party rights implied by law are, to the extent permissible by law, excluded from this Agreement. and accordingly the Agreement may be varied or amended without the consent of any third party.
18(10)	If any provision or part of a provision of this Agreement is found by a court or authority of competent jurisdiction to be void or unenforceable, that provision or part of a provision shall be deemed to be deleted from this Agreement and the remaining provisions shall continue in full force and effect. The parties shall in this event seek to agree upon a valid and enforceable provision or part of a provision to replace the provision or part of a provision found to be void or unenforceable.
18(11)	Each Party hereby acknowledges that certain laws of the various jurisdictions where this Agreement is to be performed (including without limitation, the United States Foreign Corrupt Practices Act and the European Union anti-bribery and corruption laws), prohibit any Person from offering to make or making any payment of money or anything of value, directly or indirectly, to any governmental official, political party, candidate for political office or official of a public international organization for the purpose of obtaining

29

or retaining business or providing an improper advantage. Each Party hereby represents, warrants and covenants to the other Party that, in the performance of its obligations hereunder, it has not made or offered to make, and will not make or offer to make, any such prohibited payment. In the event of a breach of any such laws, the non-breaching Party may, in its sole discretion, terminate this Agreement and the Party in breach shall fully indemnify (on an after tax basis), protect, defend and hold harmless the other Party and its Affiliates, officers, directors, agents and employees from and against any and all claims, losses and liabilities attributable to any such breach. The provisions of this Sub-Clause shall survive any termination of this Agreement.

18(12)

Any Party that now or hereafter has a right to claim sovereign immunity for itself or any of its assets hereby waives any such immunity to the fullest extent permitted by the laws of any applicable jurisdiction. This waiver includes immunity from (i) any expert determination or arbitration proceeding commenced pursuant to this Agreement; (ii) any judicial, administrative or other proceedings to aid the expert determination or arbitration commenced pursuant to this Agreement; and (iii) any effort to confirm, enforce, or execute any decision, settlement, award, judgment, service of process, execution order or attachment (including pre-judgment attachment) that results from an expert determination, mediation, arbitration or any judicial or administrative proceedings commenced pursuant to this Agreement. Each Party acknowledges that its rights and obligations hereunder are of a commercial and not a governmental nature.

IN WITNESS WHEREOF, the Parties have executed this Master EX-SHIP LNG Sales Agreement on the date first written hereinabove.

Signed for and on behalf of		Signed for and on behalf of
GAZ DE FRANCE INTERNATIONAL TRADING, S.A.S.		CHENIERE MARKETING, INC.
By:	/s/ Edward Savvage	By:	/s/ Keith Meyer
Name:	Edward Savvage	Name:	Keith Meyer
Title:	President	Title:	President

30

“Schedule A”

Form of the Specific Order

Specific Order N° : [*]

Between :	GAZ DE FRANCE INTERNATIONAL TRADING, S.A.S. as[ Seller / Buyer]
And :	CHENIERE MARKETING, INC. , as[ Seller / Buyer]

Referring to MASTER EX-SHIP LNG SALES AGREEMENT between CHENIERE MARKETING, INC. and GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. signed the , Seller and Buyer agree on the following:

The quantities shall correspond to [*] full cargo(es) of LNG on an EX-SHIP basis.

The Nominal Quantity applicable to each such cargo shall be [*] MMBtu, which the Parties have agreed upon, after having taken into account the LNG Capacity, the quality of LNG usually applicable at Seller’s Facilities, the boil-off rate usually applicable for a voyage of the LNG Ship between the Loading Port and the Discharge Port in the standard course of the LNG business, and the LNG heel.

The Price shall be P, expressed in …. per ….: [            ]

The LNG Ship shall be [            ], which LNG Capacity is equal to [            ] cubic meters.

The LNG heel that Seller is entitled to retain after unloading shall be [            ] cubic meters of LNG.

The Arrival Period shall be: [            ]

The Allowed Laytime shall be: [            ] hours.

The Loading Port shall be: [            ]

The Discharge Port shall be: [            ]

The LNG Receiving Facilities shall be: [            ]

31

The Specifications of the LNG unloaded at the Delivery Point shall when converted to a gaseous state be within the following ranges [    ]

		Minimum	Maximum
Gross Heating Value1
Wobbe Index1
Nitrogen (N2)	mole%
Methane (C1)	mole%
Ethane (C2)	mole%
Propane (C3)	mole%
i-Butane (i-C4)	mole%
n-Butane (n-C4)	mole%
Pentanes+ (C5 and Heavier)	mole%
Carbon dioxide (CO2)	ppm (volume)
Mercaptan1
Total Sulphur1

¹ Depending upon the LNG Receiving Facilities.

The Demurrage, expressed in [            ] per day, shall be: [            ]

The Cargo Underdelivery Amount for the purposes of Sub-Clause 4(4) shall be: [            ]

IN WITNESS WHEREOF, the Parties have executed this Specific Order.

AGREED AND ACCEPTED THIS          DAY OF             ,         .

Signed for and on behalf of Seller/Buyer	Signed for and on behalf of Buyer/Seller
GAZ DE FRANCE INTERNATIONAL TRADING, S.A.S.	CHENIERE MARKETING, INC.
By:	By:
Name:	Name:
Title:	Title:

32

“Schedule B”

Delivery Procedures - Measurement, Sampling and Testing

LNG sampling and composition determination on loading shall be done in accordance with the procedures followed at Seller’s Facilities.

The quantity in cubic meter and the temperature of the LNG unloaded shall be measured with the LNG Ship instrumentation in accordance with the methods described in the LNG Custody Transfer published by the GIIGNL, second edition 2001 or the industry standards used by the LNG Receiving Facility.

The mean composition of the LNG unloaded is determined with LNG Receiving Facilities instrumentation in accordance with the methods described in the LNG Custody Transfer published by the GIIGNL, second edition 2001 or the industry standards used by the LNG Receiving Facility.

The vapor phase during the unloading operations shall be taken into account in the energy balance. The mean composition of the vapor phase return to the ship is determined with LNG Receiving Facilities instrumentation in accordance with the methods described in the LNG Custody Transfer published by the GIIGNL, second edition 2001 or the industry standards used by the LNG Receiving Facility.

• Gross Heating Value (Mass Based)

The Gross Heating Value (Mass) shall be calculated by use of the method ISO 6976-1995 with combustion reference conditions of fifteen degree Celsius (15^oC.) and units of MJ/kg and 0.01 significant figures.

• Gross Heating Value (Volume Based)

The Gross Heating Value (Volume Based) shall be calculated by use of the method ISO 6976-1995 with combustion reference conditions of fifteen degree Celsius (15^oC.) and units of MJ/Nm³ and 0.01 significant figures.

• LNG Density

33

The LNG Density shall be calculated by use of the method Klosey MacKinley from NBS Technical Note 1030, December 1980, molar mass from ISO 6976-1995, units in kg/m³ and 0.01 significant figures.

• The Quantity Delivered shall be calculated in accordance with the formula given in the LNG Custody Transfer published by the GIIGNL, second edition 2001, page five (5) or the industry standards used by the LNG Receiving Facility.

For the purpose of this calculation the Quantity Delivered shall be expressed in MMBtu, rounded to two (2) decimal places.

34

“Schedule C”

Form of Notice of Arrival

From :	[LNG Ship]
To:	[Buyer]
Copy :	[Seller’s] Dispatching
SUBJECT :	NOTICE OF ARRIVAL
CARGO REFERENCE :	[    ]

Please be informed that [LNG Ship] has arrived at the PBS and obtained the authorization by the competent authorities to enter the Discharge Port on DD/MM/YY at HH:MM hr.

Regards

Master of [LNG Ship]

35

“Schedule D”

Form of Notice of Readiness

From:	[LNG Ship]
To:	[Operator of LNG Receiving Facilities]
	[Buyer]
Copy :	[Seller’s] Dispatching
SUBJECT :	NOTICE OF READINESS
CARGO REFERENCE :	[    ]

Please be informed that [LNG Ship] is ready (“to unload LNG at the berth¹” or “to proceed to berth and unload LNG²”) at the Discharge Port on DD/MM/YY at HH:MM hr.

Regards

Master of [LNG Ship]

¹ General

² In the case of Discharge Port being Isle of Grain (UK)

36

“Schedule E”

Form of EX-SHIP Certificate of Volume on Unloading

Attachment
	[Ship’s Report On Arrival]
LNG Ship :
Date of arrival :
Voyage #:
Port:

Tank	Tank # 1	Tank # 2	Tank # 3	Tank # 4	Tank # 5
Sounding [mm]
Trim Correction [mm]
Heel Correction [mm]
Corrected Sounding [mm]
Liquid Temperature [°C]
Volume [cubic meter]

Average Liquid Temperature [°C]

Volume Before Unloading [ m3]

Draft/List F: A: List:

LNG Receiving Facilities Independent Surveyor

	[Ship’s Report On Departure]
LNG:
Date:
Voyage #:
Port:

Tank	Tank # 1	Tank # 2	Tank # 3	Tank # 4	Tank # 5
Sounding [mm]
Trim Correction [mm]

37

List Correction [mm]

Corrected Sounding [mm]

Vapor Temperature [°C]

Volume [ cubic meters]

Average Vapor Temperature [°C]

Vapor Pressure [mbar]

Volume After Unloading [ m3] Density [kg/m3]

Total volume unloaded [m3] Total weight loaded/Discharged [MT]

Draft/List F: A: List:

LNG Receiving Facilities Independent Surveyor LNG Ship

38

“Schedule F”

Form of EX-SHIP Certificate of Quality on Unloading

Reference:

LNG SHIP:

Date Unloading Completed:

Nitrogen	N2	%mol	xx.xx
Carbon Dioxide	CO2	ppm vol	xx.xx
Methane	C1	%mol	xx.xx
Ethane	C2	%mol	xx.xx
Propane	C3	%mol	xx.xx
i-Butane	iC4	%mol	xx.xx
n-Butane	nC4	%mol	xx.xx
Pentanes	nC5	%mol	xx.xx

Density¹ [] xxx.x

Wobbe Index¹[ ]xxxx

Gross Heating Value¹ [] xxxx

Mercaptan (as S) ¹ [] x.xx

Total Sulphur (as S) ¹ [] x.xx

¹ Depending upon the LNG Receiving Facilities

39

LETTER AGREEMENT

between

CHENIERE MARKETING, INC.

and

GAZ DE FRANCE INTERNATIONAL TRADING S.A.S.

This letter agreement (“Letter Agreement”) has been made and entered into in Barcelona,

Spain, as of this 26^th day of April, 2007 by and between

CHENIERE MARKETING, INC., a corporation incorporated under the laws of the State of Delaware, U.S.A., with its principal offices at 700 Milam St., Suite 800, Houston, Texas U.S.A. 77002 (“Cheniere”),

and

GAZ DE FRANCE INTERNATIONAL TRADING S.A.S., a company incorporated under the laws of France with its principal offices at 2 rue Curnonsky, 75017 Paris, France (“GDF”);

Cheniere and GDF are hereinafter also referred to individually as a “Party” and collectively as the “Parties”.

Whereas :

- The Parties have simultaneously herewith executed that certain (i) GDF Transatlantic Option Agreement, (ii) Cheniere Transatlantic Option Agreement and (iii) Specific Order No.1 for 7 (seven) LNG cargoes in year 2008 under the Master Ex-Ship LNG Sales Agreement dated the same date as this Agreement (collectively, the “Agreements”).

- The Parties wish to take into account the necessary prior approval of their respective internal management committees before being bound by the Agreements.

Now therefore, the Parties have agreed as follows :

The Parties acknowledge that, notwithstanding anything in the Agreements to the contrary, the Agreements shall not become effective unless each of GDF and Cheniere obtains approval of the Agreements by either its board of directors, the board of directors of its parent company, or its relevant management committee, as it deems necessary and appropriate (“Board Approval”) by July 1^st , 2007. If the respective Board Approval of a Party is not obtained, or if the other Party has not been notified in writing of such Board Approval, by July 1^st , 2007, then the Agreements shall be null and void and shall not become effective.

The Parties hereby acknowledge that this Letter Agreement is prevailing in its interpretation on the Agreements, and that in the event of any conflict between the terms and conditions of this Letter Agreement and the terms and conditions of the Agreements, the terms and conditions of this Letter Agreement shall prevail.

This Letter Agreement is governed by the laws of England and Wales.

IN WITNESS WHEREOF, on the date hereinabove stipulated, the duly authorized representatives of the Parties hereto have executed this Agreement in 2 (two) original copies.

CHENIERE MARKETING, INC.		GAZ DE FRANCE INTERNATIONAL TRADING S.A.S.
By:	/s/ Keith Meyer	By:	/s/ Edward Savvage
Name:	Keith Meyer	Name:	Edward Savvage
Title:	President	Title:	President

Specific Order N° 1

Between :	GAZ DE FRANCE INTERNATIONAL TRADING S.A.S., as Seller
And :	CHENIERE MARKETING INC, as Buyer

Referring to the MASTER EX-SHIP LNG SALES AGREEMENT between CHENIERE MARKETING, INC. and GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. signed the 26^th April 2007 (hereinafter referred to as the “Master Sales Agreement”), Seller and Buyer agreed on the following :

1. The quantities shall correspond to seven (7) full cargo(es) of LNG on an EX-SHIP basis, each one being hereafter referred to as “LNG Cargo Lot” with its corresponding number from 1 to 7 to be on an even basis of one (1) per month between April 2008 and October 2008, subject to the selection of the Arrival Period for each LNG Cargo Lot as described hereinbelow.

2. The Nominal Quantity applicable to each LNG Cargo Lot shall be between 2,600,000 and 3,500,000 MMBtu and shall be nominated by Seller to Buyer not later than the 1^st day of the month preceding the month of the Arrival Period of each of the LNG Cargo Lots after having taken into account the LNG Capacity, the quality of LNG usually applicable at Seller’s Facilities, the boil-off rate usually applicable for a voyage of the LNG Ship between the Loading Port and the Discharge Port in the standard course of the LNG business, and the LNG Heel.

3. The Price shall be P, expressed in USD per MMBtu:

P = 94% of the final settlement price (in USD per MMBtu) on the trading exchange owned or operated by the New York Mercantile Exchange, Inc. or its successor, in the Natural Gas Futures Contract for delivery at the Henry Hub for the Prompt Month, minus (ii) US$ 0.65 per MMBtu.

Where “Prompt Month” means the calendar month during which the Arrival Period ends, provided that if the Arrival Period ends on or after the twenty fifth (25^th) day of such calendar month, then the Prompt Month shall be the following month.

4. The LNG Ship actually used by Seller for transport and delivery under this Specific Order shall be (unless otherwise agreed by the Parties), subject to Clause 6 of the Master Agreement, one of the LNG Ships listed below (as may be supplemented from time to time by the Seller) and shall be nominated by Seller not later than the 1^st day of the month preceding the month of the Arrival Period of each of the LNG Cargo Lots.

LNG Ship	Ramdane Abane	Galeomma	Edouard LD	Tenaga Satu	Maran Gas Asclepius	Provalys	Gaselys	Grace Cosmos
LNG Capacity (m3)	126,190	126,576	129,500	130,000	145,874	154,445	154,445	147,500

5. The LNG heel shall be nominated by the Seller not later than the 1^st day of the month preceding the month of the Arrival Period.

6. The Arrival Period shall be a calendar day nominated by the Seller not later than the 1^st day of the month preceding the month of the Arrival Period. Within two (2) Business Days of reception of such nomination the Buyer will either (i) confirm that the Arrival Period is acceptable, or (ii) designate an alternative Arrival Period which shall be within two days of the day originally nominated by the Seller. To the extent an alternative Arrival Period is designated, the alternative Arrival Period shall be treated as though it occurred within the originally requested month. If Buyer does not confirm the Arrival Period nominated by Seller or does not designate an alternative Arrival Period as provided for herein, the Arrival Period designated by Seller shall be considered as accepted by Buyer.

7. Cancellation Right :

Either Seller or Buyer shall have the right to cancel the delivery or reception of the LNG Cargo Lot number 1 provided for delivery at the LNG Receiving Facilities in April 2008 provided that the Party exercising such right shall notify the other Party not later than the 29^th February 2008. If either Party exercises its right to cancel the LNG Cargo Lot number 1 in accordance with the conditions stated herein, the Parties shall not be considered as having failed to perform any of their obligations with respect to such LNG Cargo Lot number 1 pursuant to this Specific Order.

Seller shall have the right to cancel the delivery of any of the six (6) LNG Cargo Lots (number 2 to number 7) provided for delivery in the time period from May to October 2008 included, and provided that :

- if Seller decides to cancel the delivery of all such six (6) LNG Cargo Lots under this Specific Order, Seller shall notify Buyer not later than the 29^th February 2008 and shall pay to Buyer an amount in USD equal to 0.25 USD x 6 x (2,600,000 + 3,500,000) / 2 (the “Total Cancellation Fee”)

- if Seller decides to cancel the delivery of any one of such six (6) LNG Cargo Lots under this Specific Order, Seller shall notify Buyer of the cancellation of the delivery of such LNG Cargo Lot not later than the 1^st day of the month preceding the deemed month of delivery of such cargo and shall pay to Buyer an amount in USD equal to 0.50 USD x (2,600,000 + 3,500,000) / 2 (the “Individual Cancellation Fee”).

Sub-Clauses 4.3 and 4.4 of the Master Sales Agreement shall not apply to any cancellation made pursuant to article 7 of the Specific Order n°1 and payment of either the Total Cancellation Fee or the Individual Cancellation Fee shall be Buyer’s sole and exclusive remedy for the decision by Seller to cancel the delivery of all or any of the LNG cargo(es) and Seller shall not be obliged to sell or deliver any replacement cargo to Buyer.

8. The Allowed Laytime shall be :

(i) in relation to an LNG Ship with a total cargo tank capacity not exceeding 145,000 m³, thirty six (36) hours;

(ii) in relation to any other LNG Ship, a period (in hours) calculated as 24 + (12 x LNG Capacity /145,000), LNG Capacity being as specified in the Specific Order.

9. The Demurrage, expressed in USD per 24 hour period, shall be one hundred thousand (100,000), prorated for any partial 24 hour period.

10. The Loading Port shall be nominated by the Seller not later than the 1^st day of the month preceding the month of the Arrival Period.

11. The Discharge Port and LNG Receiving Facilities shall be the Sabine Pass Terminal.

12. Except as provided for herebelow, the Cargo Underdelivery Amount applicable for each LNG Cargo Lot for the purposes of Sub-Clause 4(4) of the Master Sales Agreement shall be equal to the product of the Nominal Quantity multiplied by the greater of (i) the Cover Difference, or (ii) US$1.00. The “Cover Difference” shall be the difference between (i) the unweighted average of the midpoint price for Henry Hub (in USD/MMBtu) as published in Platt’s Gas Daily for each of the four (4) successive publication dates following the Arrival Period, minus (ii) eighty percent (80%) of P.

If the Seller is obliged to pay a Cargo Underdelivery Amount, and Seller has not notified Buyer of the specific Nominal Quantity and of the Arrival Period, then the Cargo Underdelivery Amount shall be the product of a deemed Nominal Quantity of (2,600,000 + 3,500,000)/2 MMBtu multiplied by the greater of (i) twenty percent (20%) of P (with P to be determined as if the Arrival Period for the respective LNG Cargo Lot was the first day of the month during which the delivery would have been made) or (ii) US$1.00.

13. The Quality Specifications of the LNG unloaded at the LNG Receiving Facilities shall when converted to a gaseous state be within the following ranges :

(a)	Hydrogen Sulphide	not more than 0.25 grains per 100 Standard Cubic Feet
(b)	Total Sulphur	not more than 1.35 grains per 100 Standard Cubic Feet
(c)	Hydrogen Content	not more than 400 PPM
(d)	Oxygen Content	not more than 0.001 mol%
(e)	Hydrocarbon Dewpoint	not more than minus two degrees Celsius (-2°C) at seventy bar gauge (70 barg) or the actual delivery pressure
(f)	Wobbe Number	shall be no greater than 1400
(g)	Carbon Dioxide	not more than 2.0 mol%
(h)	Nitrogen and other inert gases	not more than 1.5 mol%
(i)	Gross Heating Value	shall be within the range 980 and 1100 Btu per SCF and in compliance with Wobbe limits described above
(j)	Ethane (C2)	not more than 11 MOL%
(k)	Propane (C3)	not more than 3.5 MOL%
(l)	Butanes (C4) and higher	not more than 1.5 MOL%
(m)	Pentanes (C5) and heavier	not more than 0.09 MOL%

The LNG when delivered by Seller to the Sabine Pass Terminal shall contain no water, active bacteria or bacterial agents (including sulfate reducing bacteria or acid producing bacteria) or other contaminants or extraneous material.

Some of the above Specifications are based on guidelines issued by the NGC+ Interchangeability Work Group on February 28, 2005 and may be updated by Buyer if such group modifies its recommendations. Additionally, all of the Specifications are subject to being modified by Buyer if required by applicable law, by the Sabine Pass Terminal, or in order to make the regasified natural gas comply with quality specifications imposed by natural gas pipelines downstream of the Sabine Pass Terminal.

14. Credit Support : The delivery by Seller of any of the LNG Cargo Lots provided for herein shall be subject to the reception by Seller not later than the 15^th day of the month preceding the month of the Arrival Period for the applicable LNG Cargo Lot of a stand-by letter of credit, issued by a financial institution rated not less than A3 (Moody’s) or A- (Standard & Poors), substantially in the form as attached in Exhibit A. This letter of credit shall be valid until the (15^th) day of the second month following the month in which the respective Arrival Period falls. Its amount shall be equal to the product of the Nominal Quantity multiplied by the closing price (in USD per MMBtu) on the 10^th day (or the following trading day if the 10^th day is not a trading day) of the month preceding the month of the Arrival Period on the trading exchange owned or operated by the New York Mercantile Exchange, Inc. or its

successor, in the Natural Gas Futures Contract for delivery at the Henry Hub for the month of the Arrival Period. If Seller is paid in full with respect to an LNG Cargo Lot, Seller shall, upon the request of Buyer, release the associated letter of credit before the expiry date and provide documentation as requested by the issuer to evidence such release.

15. Diversion to Another Terminal : By giving Seller notice at least six (6) days prior to the scheduled Arrival Period, Buyer may request that the affected cargo be delivered at an alternate receiving terminal in North America where Buyer may have regasification capacity. Seller shall accept that diversion provided:

(i) that it shall not prevent the LNG Ship from meeting the loading window for its next scheduled cargo lifting, and that the LNG Ship is compatible and accepted in such alternate receiving terminal, and

(ii) that Buyer pays Seller the incremental costs incurred by Seller, if any, in diverting the LNG cargo to the alternative terminal.

16. Insurance and Port Liability Agreement : Seller shall cause any LNG Ship to be used by it to make deliveries of LNG pursuant hereto to have usual and customary protection and indemnity insurance (from an International Group Protection & Indemnity (“P&I”) Club), based on normal industry practice, ensuring standard coverage for standard P&I risks, including wreck, debris removal, pollution, collision liability and civil liability protection in accordance with any requirements of the Sabine Pass Terminal as the LNG Receiving Facilities, but in each case in a face amount of US$150,000,000. Seller shall also cause each LNG Ship to be used by it to make deliveries of LNG pursuant to an exercised option to enter into the usual and customary port liability agreement required by the LNG Receiving Facilities which shall be, in the case of deliveries to the Sabine Pass Terminal as the LNG Receiving Facilities, substantially in the form of that attached hereto as Exhibit B and subject to final confirmation of the relevant P&I Club.

17. Conditions Precedent :

- Each Party having obtained approval of this Specific Order by its, or its parent company’s, Board of Directors (or any other corporate authorisation) not later than July 1, 2007.

- The Parties having determined the compatibility with respect to at least four (4) of the LNG Ships listed in Article 4 herein with the Sabine Pass Terminal not later than July 1, 2007.

IN WITNESS WHEREOF, the Parties have executed this Specific Order in 2 (two) original copies.

AGREED AND ACCEPTED THIS 26^th DAY OF APRIL, 2007

Signed for and on behalf of Seller		Signed for and on behalf of Buyer
GAZ DE FRANCE INTERNATIONAL TRADING S.A.S.		CHENIERE MARKETING INC.
By:	/s/ Edward Savvage	By:	/s/ Keith Meyer
Name:	Edward Savvage	Name:	Keith Meyer
Title:	President	Title:	President

EXHIBIT A

FORM OF LETTER OF CREDIT

            , 20    

Gentlemen:

We hereby establish our irrevocable standby letter of credit No.             in favor of GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. (“Beneficiary”) for the account of CHENIERE MARKETING, INC, in the amount of [Insert number calculated pursuant to Article 14 of the Specific Order n° 1], available to Beneficiary against presentation to us of a sight draft at [list office(s), branch(es), other locations(s)] with notation that the same is drawn under this letter of credit, identifying the same by number. This Letter of Credit shall expire at 5:00 p.m. (             time) on             , 20     [insert pursuant to Article 14 of the Specific Order n° 1]. Notwithstanding the above, in the event of disputes of an invoice this letter of credit shall not expire until the resolution of such dispute. [this last sentence subject to bank’s approval.]

Your sight draft shall be accompanied by a statement on Beneficiary’s letterhead purportedly signed by an authorized officer of Beneficiary stating: “I hereby certify that GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. is entitled to draw under your letter of credit No.                      pursuant to the terms of that certain Specific Order No. 1, dated as of April [ ] 2007 issued under the Master Ex-ship LNG Sales Agreement, dated as of [            ] 2007, between GAZ DE FRANCE INTERNATIONAL TRADING S.A.S. and CHENIERE MARKETING, INC.”

The term “Beneficiary” includes any successor to the Beneficiary, including, without limitation, any liquidator, receiver or successor by merger.

The amount which may be drawn by Beneficiary under this Letter of Credit shall be automatically reduced by the amount of any drawing hereunder. Any number of partial drawings are permitted from time to time hereunder.

We hereby undertake with Beneficiary that documents drawn under and in compliance with the terms of this letter of credit shall be duly honored upon presentation as specified.

This letter of credit shall be governed by, subject to and construed in accordance with the Uniform Customs and Practices for Documentary Credits, 1993 Revision, International Chamber of Commerce Publication No. 500, and, to the extent not addressed thereby, laws of England and Wales. Notwithstanding Article 17 of said publication, if this credit expires during an interruption of business as described in Article 17 we agree to effect payment if the credit is drawn against within thirty (30) days after resumption of business. [This paragraph will be revised to be consistent with UCP 600 when it becomes effective]

[BANK]

By:

Name:

Title:

EXHIBIT B

FORM OF PORT LIABILITY AGREEMENT

PORT LIABILITY AGREEMENT

THIS PORT LIABILITY AGREEMENT (this “Agreement”) is effective as of             , 20    , and is made by and between [INSERT NAME OF OPERATOR], a [TYPE OF ENTITY AND JURISDICTION OF ORGANIZATION] (“Operator”), and [INSERT NAME OF VESSEL OWNER], a [TYPE OF ENTITY AND JURISDICTION OF ORGANIZATION] (“Vessel Owner”).

RECITALS

WHEREAS, Vessel Owner, using the LNG vessel set forth below under its name and signature (“Vessel”), proposes to deliver certain quantities of liquefied natural gas to Operator at its marine terminal and receiving, storage and regasification facilities located in,                      (as more fully defined below, the “Marine Terminal”); and

WHEREAS, Vessel Owner and Operator (collectively, the “Parties” and individually a “Party”) have agreed to allocate the risk of and responsibility for loss and damage resulting from an Incident (as defined below) at the Marine Terminal in the following manner;

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows:

1. The following terms shall have the following meanings when used herein:

“Affiliate” means, with respect to any Person, any other Person which, directly or indirectly, controls, is controlled by, or is under common control with, such Person. For purposes of this definition, “control” (including, with correlative meanings, the terms “controlled by” and “under common control with”) means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a Person, whether through the ownership of voting securities or otherwise.

“Incident” means any occurrence or series of occurrences having the same origin arising out of or relating to the Vessel’s use of the Marine Terminal in which there is any one or more of the following: (i) loss of or damage to the Marine Terminal or the Vessel; (ii) injury to the employees and agents comprising Terminal Interests or Vessel Interests; (iii) loss or damage, other than to the Marine Terminal or the Vessel, caused or contributed to by the Vessel, including but not limited to, injury to third parties or damage to the property of third parties; or (iv) an obstruction or danger affecting or interfering with the normal operation of the Marine Terminal or the Port.

“Terminal Interests” means: (i) Operator; (ii) all Affiliates of Operator; (iii) all Persons (other than the Vessel Interests and Persons providing fire boats, tugs and escort vessels to Vessel at the Port) employed or providing services at the Marine Terminal in connection with the unloading, storage, or regasification of LNG at the Marine Terminal; and (iv) the employees and agents of all Persons referred to in this paragraph.

“Marine Terminal” means Operator’s marine terminal and LNG receiving, storage and regasification facilities located at the Port, including all berths, buoys, gear, craft, equipment, plant, facilities and property of any kind (whether afloat or ashore) located thereat or adjacent thereto and in the ownership, possession or control of the Terminal Interests.

“Person” means any individual, firm, corporation, trust, partnership, association, joint venture (incorporated or unincorporated), or other business entity.

“Port” means the port at or near                     , including its anchorage, turning basin and approaches into the Marine Terminal associated therewith.

“Vessel Interests” means: (i) Vessel Owner; (ii) all Affiliates participating in the ownership and/or operation of Vessel; (iii) all Persons (other than the Terminal Interests) participating, employed, or providing services in connection with the ownership or operation (including all operations related to navigation and berthing/unberthing) of the Vessel; and (iv) the employees and agents of all Persons referred to in this paragraph.

2. In all circumstances, the master of the Vessel shall remain solely responsible on behalf of the Vessel Interests for the proper navigation and safety of the Vessel and her cargo.

3. Any liability arising from an Incident shall, as between the Vessel Interests and the Terminal Interests, be borne: (i) by the Vessel Interests alone, if the Vessel Interests are wholly or partially at fault and the Terminal Interests are not at fault; (ii) by the Terminal Interests alone, if the Terminal Interests are wholly or partially at fault and the Vessel Interests are not at fault; (iii) by the Vessel Interests and the Terminal Interests, in proportion to the degree of their respective fault, if both are at fault and the degree of such fault can be established; or (iv) by the Vessel Interests and the Terminal Interests equally if neither of them appears to be at fault or it is not possible to establish the degree of their respective fault. In this regard, any acts or omissions of Persons providing fire boats, tugs and escort vessels to Vessel at the Port shall be deemed to be the responsibility of the Vessel Interests.

4.

(i) Operator shall be solely responsible for claims brought by any employee and/or member of the family or dependent of any employee of Operator arising out of or consequent upon the personal injury, loss or damage to property of, or death of such employee, family member or dependent, and Operator shall indemnify and hold any Vessel Owner harmless in the event any such employee, or any family member or dependent thereof, or the executor, administrator, or personal representative of any of the foregoing, shall bring such a claim against any Vessel Owner.

(ii) The Vessel Owners shall be solely responsible for claims brought by any employee and/or member of the family or dependent of any employee of any Vessel Owner arising out of or consequent upon the personal injury, loss or damage to property of, or death of such employee, family member or dependent, and each Vessel Owner shall indemnify and hold Operator harmless in the event any such employee, or any family member or dependent thereof, or the executor, administrator or personal representative of any of the foregoing, shall bring such claim against Operator.

(iii) Operator and the Vessel Owners shall consult together to the extent practicable before either makes any payment which would fall due to be indemnified by the other under the terms of

Sections 4(i) or 4(ii). The indemnities contained in Sections 4(i) and 4(ii) are separate and distinct from, and independent of, the obligations undertaken and the responsibilities and exceptions from and the limitations of liability provided in Sections 2, 3, 5 and 6 of this Agreement.

(iv) The cross indemnities provided in this Section 4 are intended to be binding regardless of fault or negligence on the part of the party in whose favor they are being given.

5.

(i) Subject to Section 6(ii) below, the total aggregate liability of the Vessel Interests to the Terminal Interests, however arising, in respect of any one Incident, shall not exceed one hundred fifty million U.S. dollars ($150,000,000). Payment of an aggregate sum of one hundred fifty million U.S. dollars ($150,000,000) to any one or more of the Terminal Interests in respect of any one Incident shall be a complete defense to any claim, suit or demand relating to such Incident made by the Terminal Interests against the Vessel Interests. The liability of the Vessel Interests hereunder shall be joint and several.

(ii) Vessel Interests shall provide to the Terminal Interests at all times sufficient written evidence that the Vessel’s Protection and Indemnity Association has agreed to: (a) cover the Vessel Interests as a member of the Association against the liabilities and responsibilities provided for in this Agreement in accordance with its Rules; (b) give the Terminal Interests prior notice of cancellation of the Vessel’s entry in such Protection and Indemnity Association; and (c) waive in favor of the Terminal Interests all rights of subrogation of claims by the Protection and Indemnity Association against the Terminal Interests to the extent such claims have been waived in this Agreement by the Vessel Interests.

6. As to matters subject to this Agreement and regardless of fault or negligence on the part of any Party, with respect to an Incident:

(i) except to the extent expressly preserved in this Agreement, Terminal Interests hereby expressly, voluntarily and intentionally waive any right or claims they might otherwise have against the Vessel Interests under applicable laws or under any port liability agreement or similar port conditions of use previously signed by the Master for the Port; and

(ii) except to the extent expressly preserved in this Agreement, Vessel Interests hereby expressly, voluntarily and intentionally waive any rights to limit their liability under the United States Limitation of Vessel Owners Liability Act or any other similar law or convention, as applicable. Such waiver shall include any right to petition a court, arbitral tribunal or other entity for limitation of liability, any right to claim limitation of liability as a defense in an action, and any other similar right under relevant law. The foregoing waivers shall apply to all Persons claiming through the Terminal Interests or through the Vessel Interests.

7. The substantive law of New York, without regard to any conflicts of law principles that could require the application of any other law, shall govern the interpretation of this Agreement and any dispute, controversy, or claim arising out of, relating to, or in any way connected with this Agreement, including, without limitation, the existence, validity, performance, or breach hereof.

8. If and for so long as any provision of this Agreement shall be deemed to be judged invalid for any reason whatsoever, such invalidity shall not affect the validity or operation of any other provision of this Agreement except only so far as shall be necessary to give effect to the construction of such invalidity, and any such invalid provision shall be deemed severed from this Agreement without affecting the validity of the balance of this Agreement.

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their duly authorized representatives effective as of the date first set forth above.

OPERATOR	VESSEL OWNER
[INSERT NAME OF OPERATOR]	[INSERT NAME OF VESSEL OWNER]
By:	By:
Title:	Title:
	As owner of the [Name of Vessel]
	Registration No. [                     ]
	State of Registry [                     ]

EX-10.3

Exhibit 10.3

GDF TRANSATLANTIC OPTION AGREEMENT

This GDF Transatlantic Option Agreement (the “Agreement”), dated as of this 26^th day of April, 2007 (the “Effective Date”), is made by and between CHENIERE MARKETING, INC., a corporation incorporated under the laws of the State of Delaware, U.S.A., with its principal offices at 700 Milam St., Suite 800, Houston, Texas U.S.A. 77002 (“Buyer”), and GAZ DE FRANCE INTERNATIONAL TRADING S.A.S., a company incorporated under the laws of France with its principal offices at 2 rue Curnonsky, 75017 Paris, France (“Seller”). Seller and Buyer may be referred to individually as a “Party” or collectively as the “Parties”.

WHEREAS, from time to time Seller may have a cargo of liquefied natural gas (“LNG”) that it desires to sell to Buyer;

WHEREAS, Buyer has contracted for terminal capacity at the Sabine Pass Terminal, located on the Sabine-Neches Waterway in Cameron Parish, Louisiana, United States of America (the “Sabine Pass Terminal”);

WHEREAS, from time to time, Buyer may have regasification capacity at other LNG receiving terminals in North America (the “Alternate NA Terminals”);

WHEREAS, Buyer desires to grant to Seller an option to sell cargos of LNG to Buyer in accordance with the terms and conditions hereof and that certain Master Ex-Ship LNG Sales Agreement executed on April 26^th, 2007 (the “Master Sales Agreement”).

NOW, THEREFORE, in consideration of the mutual covenants set forth herein and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged by the Parties hereto, Seller and Buyer hereby agree as follows:

Article I

Transatlantic Options

1.1 Grant of Option. Buyer hereby grants to Seller the option to sell one (1) cargo of LNG per month for each and every month during the Option Period. The cargoes tendered for sale shall be delivered on an LNG Ship, in whole cargo lots, between eighty-eight thousand (88,000) and one hundred and fifty five thousand (155,000) cubic meters per cargo. Each monthly option shall be specifically exercised for each cargo separately by way of a Specific Order pursuant to the Master Sales Agreement. Seller is not obligated to exercise any option with respect to any month but Buyer, subject to the rules hereafter defined, shall be obliged to purchase and take delivery of any cargo of LNG in case Seller exercises an option pursuant to the following principles stated in this Agreement.

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1.2 Scheduling. As early as possible and not later than the fifth (5^th) of December of any year within the Option Period, Buyer will provide Seller with an annual program setting the dates of two (2) unloading slots for a cargo of LNG (the “Potential Arrival Period”) it has been allocated at the Sabine Pass Terminal in each month of the following calendar year, spread evenly throughout a month and across months to the extent reasonably practicable (the “Terminal Annual Program”).

Not later than five (5) Business Days after the reception of the Terminal Annual Program, Seller shall notify Buyer of one (1) Potential Arrival Period per month it is willing to elect as the Arrival Period in case it exercises its option to sell in such month (the “Election Notice”). Buyer shall endeavor to accept the Potential Arrival Periods proposed by Seller in its Election Notice but shall not be obliged to accept any Potential Arrival Period which is not the first Potential Arrival Period of the relevant month as stated in the Terminal Annual Program. The list of the Potential Arrival Periods accepted by Buyer (the “Option Annual Program”), which must be at least one slot per month, shall be notified by Buyer to Seller not later than the later of (i) the twentieth (20^th) day of December of the year preceding the year on which the Terminal Annual Program applies, and (ii) the fifteenth (15^th) Business Day after the reception of the Election Notice.

Any modification made by the operator of the Sabine Pass Terminal that affects the Option Annual Program shall be immediately notified by Buyer to Seller, and the Parties shall discuss in good faith to find a mutually agreeable solution.

The Parties hereby recognize that the principles stated herein may not be applicable for the time period between the beginning of the Option Period and the end of the first calendar year of the Option Period, and each Party shall make its reasonable endeavors in order to set up and implement the Option Annual Program applicable to this time period pursuant to the principles stated in this Agreement.

1.3 Exercise of Option. If Seller desires to exercise its option to sell a cargo of LNG to Buyer during any month in the Option Period, Seller shall provide, as its “Option Exercise Notice”, Buyer with Seller’s proposed Specific Order not later than the twentieth (20^th) day of the second (2^nd) month preceding the month within which the first (1^st) hour of the Arrival Period falls. The proposed Specific Order shall be completed in accordance with the terms and conditions of this Agreement and the Master Sales Agreement, delivered in accordance with the delivery instructions set forth in the Master Sales Agreement and already executed by Seller. In particular the Arrival Period specified in the proposed Specific Order shall be the Potential Arrival Period of the relevant month as set forth in the Option Annual Program. Provided the Specific Order is completed in accordance with the terms and conditions of this Agreement and the Master Sales Agreement and contains no material mistakes or omissions, Buyer shall execute the Specific Order and send it back to Seller not later than the twenty fifth (25^th) day of the

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second (2^nd) month preceding the month within which the first (1^st) hour of the Arrival Period falls. If Buyer believes that the Specific Order submitted by Seller contains a material mistake or omission, Buyer shall send Seller a notice of such material mistake or omission by the date specified in the preceding sentence, and the Parties shall work together in good faith to resolve the material mistake or omission and develop a corrected Specific Order for execution by both Parties. If Buyer fails to send Seller the executed Specific Order, provided that such Specific Order contains no material mistake or omission, and the Parties fail to mutually agree upon a solution before the first (1^st) day of the month preceding the month within which the first (1^st) hour of the Arrival Period falls, Buyer shall be considered as having failed to take delivery of the LNG cargo specified in the proposed Specific Order and the provisions of Sub-Clause 4.3 of the Master Sales Agreement shall apply. In this particular case, Seller shall be allowed to invoice such LNG cargo as soon as the information requested for the Price calculation is available.

If Seller fails to give its Option Election Notice by the time specified in the first paragraph of this Sub-Clause 1.3, the option for such month shall expire and Seller shall have no right to exercise an option to sell to Buyer for that particular month. For the avoidance of doubt, the decision not to exercise an option for any given month does not affect the rights of Seller in future months. In the event Seller submits a Specific Order as its Option Exercise Notice, certain provisions of the form of such Specific Order shall be completed as follows:

(a) Demurrage shall be one hundred thousand (100,000) US$ per 24 hour period, or prorata for any partial 24 hour period.

(b) The Cargo Underdelivery Amount shall be equal to the product of the Nominal Quantity multiplied by the greater of (i) the Cover Difference, or (ii) US$1.00. The “Cover Difference” shall be the amount calculated as (i) minus (ii), with (i) and (ii) being as follows:

(i) means the unweighted average of the midpoint price for Henry Hub as published in Platt’s Gas Daily (or another publication reasonably selected by Buyer if such publication is no longer publishing such data provided the substitute data results in approximately the same economic value) for each of the four (4) successive publication dates following the Arrival Period,

(ii) means eighty percent (80%) of P.

(c) The Specifications shall be as set forth in Exhibit A.

(d) The Allowed Laytime shall be as follows:

(i) in relation to an LNG Ship with a total cargo tank capacity not exceeding 145,000 m³, thirty-six (36) hours;

(ii) in relation to any other LNG Ship, a period (in hours) calculated as 24 + (12 x LNG Capacity /145,000); LNG Capacity being as specified in the Specific Order.

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1.4 Alternative Terminal. By giving Seller notice at least six (6) days prior to the scheduled Arrival Period, Buyer may request that the affected cargo be delivered at an Alternate NA Terminal. Seller shall accept that diversion provided:

(i) that it shall not prevent the LNG Ship from meeting the loading window for its next scheduled cargo lifting, and

(ii) that Buyer pays Seller the incremental costs incurred by Seller, if any, in diverting the LNG cargo to the alternative terminal.

1.5 Price. The Price (P) under this Agreement and the Specific Order for the respective exercised option shall be as follows:

Ninety four percent (94.0%) of the final settlement price (in USD per MMBtu) of the Natural Gas Futures Contract (for delivery at Henry Hub) traded on the exchange owned by New York Mercantile Exchange, Inc. or its successor, for the Prompt Month, minus US $0.65 per MMBtu. “Prompt Month” means the calendar month during which the Arrival Period ends, provided that if the Arrival Period ends on or after the 25^th day of such calendar month, the Prompt Month shall be the next following calendar month.

Each invoice shall be prepared in USD.

1.6 Insurance and Liability of LNG Vessel. Seller shall cause any LNG Ship to be used by it to make deliveries of LNG pursuant to an exercised option to have usual and customary protection and indemnity insurance (from an International Group Protection & Indemnity (“P&I”) Club), based on normal industry practice, ensuring standard coverage for standard P&I risks, including wreck, debris removal, pollution, collision liability and civil liability protection in accordance with any requirements of the LNG Receiving Facilities, but in each case in a face amount of US$150,000,000. Seller shall also cause each LNG Ship to be used by it to make deliveries of LNG pursuant to an exercised option to enter into the usual and customary port liability agreement required by the LNG Receiving Facilities which shall be, in the case of deliveries to the Sabine Pass Terminal, substantially in the form of that attached hereto as Exhibit B and subject to final confirmation of the relevant P&I Club.

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Article II

Term, Option Period and Suspension

2.1 Term and Option Period. This Agreement shall become effective on the Effective Date and shall remain in full force and effect until the end of the Option Period (the “Term”). The Option Period shall be that period of time commencing on the first (1^st) day of the month following the later of (i) the Commercial Start Up of the first expansion of the Isle of Grain Terminal for which GDF has contracted for capacity, or (ii) the Commercial Start Up of the Sabine Pass Terminal; and continuing until the fifteenth (15^th) anniversary of the first (1^st) day of the Option Period. Seller shall notify Buyer as soon as reasonably possible of the Commercial Start Up of the Isle of Grain Terminal expansion, and Buyer shall notify Seller as soon as reasonably possible of the Commercial Start Up of the Sabine Pass Terminal.

2.2 Early Termination. Notwithstanding anything herein to the contrary, this Agreement shall terminate automatically upon the termination of the Master Sales Agreement pursuant to Sub-Clause 18(4) thereof or upon the termination of the Cheniere Transatlantic Option Agreement.

2.3 Right to Suspend Deliveries in Case of Default of Payment. If payment by Buyer of any invoice for any cargo of LNG delivered hereunder (or for quantities of LNG not taken) and for which Buyer is obligated to pay pursuant to this Agreement and to the Master Sales Agreement is not made within five (5) Days after the due date thereof (a “Payment Failure”), Seller shall be entitled without prejudice to any of its rights under this Agreement or the Master Sales Agreement and at law or otherwise, upon giving three (3) Days notice to Buyer, to suspend subsequent deliveries of cargo of LNG to Buyer (that could have been agreed by execution of any other Specific Order) until the amount of any invoices sent by Seller to Buyer, together with interest thereon, has been paid. Such suspension shall not constitute a failure by Seller to deliver such quantity.

2.4 Failure to Issue a Program. If Buyer fails to issue either the Terminal Annual Program or the Option Annual Program (provided that Seller has previously issued the Election Notice in accordance with Sub-Clause 1.2 of this Agreement) in any year during the Option Period as provided for in this Agreement within ten (10) days after the receipt of Seller’s written notice to Buyer of such failure, Seller shall be entitled upon giving ten (10) Business Days prior written notice to Buyer, to be sent not later than the last day of January of the year for which the relevant program has not been issued by Buyer, to terminate this Agreement. If Seller terminates this Agreement in accordance with this Sub-Clause 2.4 it shall be entitled to recover liquidated damages from Buyer, calculated as the product of :

(i) fifty percent (50.0%), multiplied by

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(ii) the product of (a) the unweighted average of the settlement prices (in USD per MMBtu) on the date that the notice of termination is sent, or if such day is not a trading day, then on the next open trading day, of Natural Gas Futures Contracts (for delivery at Henry Hub) traded on the exchange owned by New York Mercantile Exchange, Inc. or its successor, for the prompt twelve (12) months for which the associated Natural Gas Futures Contracts are trading, multiplied by (b) twelve (12), multiplied by (c) 3,000,000 MMBtu.

Provided that Seller has previously received the Terminal Annual Program in accordance with Sub-Clause 1.2 above, if Seller fails to notify Buyer with its Election Notice in accordance with Sub-Clause 1.2 above, unless otherwise agreed by the Parties, Seller shall be considered as having given up the possibility to exercise any sale option pursuant to this Agreement for the year subject to the corresponding Terminal Annual Program. For the avoidance of doubt this event shall not be considered as an event of termination of this Agreement.

Article III

Notices

3.1 Addresses for Notices. Notices to be delivered hereunder shall be delivered in accordance with the notice provisions of the Master Sales Agreement.

Article IV

Miscellaneous

4.1 Definitions. Capitalized terms used herein but not defined herein shall have the meanings ascribed to them in the Master Sales Agreement. The Sabine Pass Terminal and each Alternate NA Terminal shall be deemed to be “LNG Receiving Facilities” under the Master Sales Agreement even though not referred to as such in this Agreement.

“Cheniere Transatlantic Option Agreement” means an agreement with such title that has been executed by the Parties on the same date as this Agreement pursuant to which Seller has granted Buyer an option to sell cargoes of LNG to Seller.

“Commercial Start Up” means:

- in the case of expansion of the Isle of Grain Terminal, the date of the first one of the unloading slots allocated on an even basis to Seller at the expansion of Isle of Grain Terminal

6

- in the case of the Sabine Pass Terminal, the date on which the commissioning of the Sabine Pass Terminal has been completed and the Sabine Pass Terminal is ready to commence receiving non-commissioning cargoes from Buyer under their long term terminal use agreement.

“GBP” means the legal currency of the United Kingdom.

“Isle of Grain Terminal” means that certain LNG regasification terminal located on the Medway River, Kent, England.

4.2 Assignment. Either Party may assign this Agreement to an Affiliate of such Party without the consent of the other Party. This Agreement may not be assigned by a Party to a non-Affiliate without the other Party’s prior written consent.

4.3 Conflict of Terms. If there is a conflict between any terms and conditions set forth in a Specific Order, this Agreement, or the Master Sales Agreement, the terms and conditions in the documents in the order listed shall control.

4.4 Incorporation by Reference. The Master Sales Agreement is incorporated herein by reference.

4.5 Good Faith Negotiation. If at any time the Master Sales Agreement is terminated (other than by mutual agreement or pursuant to Sub-Clause 18(4) thereof) such that the intent and purpose of this Agreement cannot be realized, the Parties will meet and negotiate in good faith to develop a solution such that the intent and purpose of this Agreement can be realized.

IN WITNESS WHEREOF, the Parties have executed this Agreement in multiple originals.

CHENIERE MARKETING, INC.		GAZ DE FRANCE INTERNATIONAL TRADING S.A.S.
By:	/s/ Keith Meyer	By:	/s/ Edward Savvage
Name:	Keith Meyer	Name:	Edward Savvage
Title:	President	Title:	President

7

EXHIBIT A

SPECIFICATIONS

Specifications for LNG to be delivered at the Sabine Pass Terminal when converted into a gaseous state shall be as follows:

(a)	Hydrogen Sulphide	not more than 0.25 grains per 100 Standard Cubic Feet
(b)	Total Sulphur	not more than 1.35 grains per 100 Standard Cubic Feet
(c)	Hydrogen Content	not more than 400 PPM
(d)	Oxygen Content	not more than 0.001 mol%
(e)	Hydrocarbon Dewpoint	not more than minus two degrees Celsius (-2°C) at seventy bar gauge (70 barg) or the actual delivery pressure
(f)	Wobbe Number	shall be no greater than 1400
(g)	Carbon Dioxide	not more than 2.0 mol%
(h)	Nitrogen and other inert gases	not more than 1.5 mol%
(i)	Gross Heating Value	shall be within the range 980 and 1100 Btu per SCF and in compliance with Wobbe limits described above
(j)	Ethane (C2)	not more than 11 MOL%
(k)	Propane (C3)	not more than 3.5 MOL%
(l)	Butanes (C4) and higher	not more than 1.5 MOL%
(m)	Pentanes (C5) and heavier	not more than 0.09 MOL%

The LNG when delivered by Seller to the Sabine Pass Terminal shall contain no water, active bacteria or bacterial agents (including sulfate reducing bacteria or acid producing bacteria) or other contaminants or extraneous material.

Some of the above Specifications are based on guidelines issued by the NGC+ Interchangeability Work Group on February 28, 2005 and may be updated by Buyer if such group modifies its recommendations. Additionally, all of the Specifications are subject to being modified by Buyer if required by applicable law, by the Sabine Pass Terminal, or in order to make the regasified natural gas comply with quality specifications imposed by natural gas pipelines downstream of the Sabine Pass Terminal.

8

EXHIBIT B

FORM OF PORT LIABILITY AGREEMENT

PORT LIABILITY AGREEMENT

THIS PORT LIABILITY AGREEMENT (this “Agreement”) is effective as of             , 20    , and is made by and between [INSERT NAME OF OPERATOR], a [TYPE OF ENTITY AND JURISDICTION OF ORGANIZATION] (“Operator”), and [INSERT NAME OF VESSEL OWNER], a [TYPE OF ENTITY AND JURISDICTION OF ORGANIZATION] (“Vessel Owner”).

RECITALS

WHEREAS, Vessel Owner, using the LNG vessel set forth below under its name and signature (“Vessel”), proposes to deliver certain quantities of liquefied natural gas to Operator at its marine terminal and receiving, storage and regasification facilities located in,                      (as more fully defined below, the “Marine Terminal”); and

WHEREAS, Vessel Owner and Operator (collectively, the “Parties” and individually a “Party”) have agreed to allocate the risk of and responsibility for loss and damage resulting from an Incident (as defined below) at the Marine Terminal in the following manner;

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows:

1. The following terms shall have the following meanings when used herein:

“Affiliate” means, with respect to any Person, any other Person which, directly or indirectly, controls, is controlled by, or is under common control with, such Person. For purposes of this definition, “control” (including, with correlative meanings, the terms “controlled by” and “under common control with”) means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a Person, whether through the ownership of voting securities or otherwise.

“Incident” means any occurrence or series of occurrences having the same origin arising out of or relating to the Vessel’s use of the Marine Terminal in which there is any one or more of the following: (i) loss of or damage to the Marine Terminal or the Vessel; (ii) injury to the employees and agents comprising Terminal Interests or Vessel Interests; (iii) loss or damage, other than to the Marine Terminal or the Vessel, caused or contributed to by the Vessel, including but not limited to, injury to third parties or damage to the property of third parties; or (iv) an obstruction or danger affecting or interfering with the normal operation of the Marine Terminal or the Port.

“Terminal Interests” means: (i) Operator; (ii) all Affiliates of Operator; (iii) all Persons (other than the Vessel Interests and Persons providing fire boats, tugs and escort vessels to Vessel at the Port) employed or providing services at the Marine Terminal in connection with the unloading, storage, or regasification of LNG at the Marine Terminal; and (iv) the employees and agents of all Persons referred to in this paragraph.

“Marine Terminal” means Operator’s marine terminal and LNG receiving, storage and regasification facilities located at the Port, including all berths, buoys, gear, craft, equipment, plant, facilities and property of any kind (whether afloat or ashore) located thereat or adjacent thereto and in the ownership, possession or control of the Terminal Interests.

9

“Person” means any individual, firm, corporation, trust, partnership, association, joint venture (incorporated or unincorporated), or other business entity.

“Port” means the port at or near                     , including its anchorage, turning basin and approaches into the Marine Terminal associated therewith.

“Vessel Interests” means: (i) Vessel Owner; (ii) all Affiliates participating in the ownership and/or operation of Vessel; (iii) all Persons (other than the Terminal Interests) participating, employed, or providing services in connection with the ownership or operation (including all operations related to navigation and berthing/unberthing) of the Vessel; and (iv) the employees and agents of all Persons referred to in this paragraph.

2. In all circumstances, the master of the Vessel shall remain solely responsible on behalf of the Vessel Interests for the proper navigation and safety of the Vessel and her cargo.

3. Any liability arising from an Incident shall, as between the Vessel Interests and the Terminal Interests, be borne: (i) by the Vessel Interests alone, if the Vessel Interests are wholly or partially at fault and the Terminal Interests are not at fault; (ii) by the Terminal Interests alone, if the Terminal Interests are wholly or partially at fault and the Vessel Interests are not at fault; (iii) by the Vessel Interests and the Terminal Interests, in proportion to the degree of their respective fault, if both are at fault and the degree of such fault can be established; or (iv) by the Vessel Interests and the Terminal Interests equally if neither of them appears to be at fault or it is not possible to establish the degree of their respective fault. In this regard, any acts or omissions of Persons providing fire boats, tugs and escort vessels to Vessel at the Port shall be deemed to be the responsibility of the Vessel Interests.

4.

(i) Operator shall be solely responsible for claims brought by any employee and/or member of the family or dependent of any employee of Operator arising out of or consequent upon the personal injury, loss or damage to property of, or death of such employee, family member or dependent, and Operator shall indemnify and hold any Vessel Owner harmless in the event any such employee, or any family member or dependent thereof, or the executor, administrator, or personal representative of any of the foregoing, shall bring such a claim against any Vessel Owner.

(ii) The Vessel Owners shall be solely responsible for claims brought by any employee and/or member of the family or dependent of any employee of any Vessel Owner arising out of or consequent upon the personal injury, loss or damage to property of, or death of such employee, family member or dependent, and each Vessel Owner shall indemnify and hold Operator harmless in the event any such employee, or any family member or dependent thereof, or the executor, administrator or personal representative of any of the foregoing, shall bring such claim against Operator.

(iii) Operator and the Vessel Owners shall consult together to the extent practicable before either makes any payment which would fall due to be indemnified by the other under the terms of Sections 4(i) or 4(ii). The indemnities contained in Sections 4(i) and 4(ii) are separate and distinct from, and independent of, the obligations undertaken and the responsibilities and exceptions from and the limitations of liability provided in Sections 2, 3, 5 and 6 of this Agreement.

10

(iv) The cross indemnities provided in this Section 4 are intended to be binding regardless of fault or negligence on the part of the party in whose favor they are being given.

5.

(i) Subject to Section 6(ii) below, the total aggregate liability of the Vessel Interests to the Terminal Interests, however arising, in respect of any one Incident, shall not exceed one hundred fifty million U.S. dollars ($150,000,000). Payment of an aggregate sum of one hundred fifty million U.S. dollars ($150,000,000) to any one or more of the Terminal Interests in respect of any one Incident shall be a complete defense to any claim, suit or demand relating to such Incident made by the Terminal Interests against the Vessel Interests. The liability of the Vessel Interests hereunder shall be joint and several.

(ii) Vessel Interests shall provide to the Terminal Interests at all times sufficient written evidence that the Vessel’s Protection and Indemnity Association has agreed to: (a) cover the Vessel Interests as a member of the Association against the liabilities and responsibilities provided for in this Agreement in accordance with its Rules; (b) give the Terminal Interests prior notice of cancellation of the Vessel’s entry in such Protection and Indemnity Association; and (c) waive in favor of the Terminal Interests all rights of subrogation of claims by the Protection and Indemnity Association against the Terminal Interests to the extent such claims have been waived in this Agreement by the Vessel Interests.

6. As to matters subject to this Agreement and regardless of fault or negligence on the part of any Party, with respect to an Incident:

(i) except to the extent expressly preserved in this Agreement, Terminal Interests hereby expressly, voluntarily and intentionally waive any right or claims they might otherwise have against the Vessel Interests under applicable laws or under any port liability agreement or similar port conditions of use previously signed by the Master for the Port; and

(ii) except to the extent expressly preserved in this Agreement, Vessel Interests hereby expressly, voluntarily and intentionally waive any rights to limit their liability under the United States Limitation of Vessel Owners Liability Act or any other similar law or convention, as applicable. Such waiver shall include any right to petition a court, arbitral tribunal or other entity for limitation of liability, any right to claim limitation of liability as a defense in an action, and any other similar right under relevant law. The foregoing waivers shall apply to all Persons claiming through the Terminal Interests or through the Vessel Interests.

7. The substantive law of New York, without regard to any conflicts of law principles that could require the application of any other law, shall govern the interpretation of this Agreement and any dispute, controversy, or claim arising out of, relating to, or in any way connected with this Agreement, including, without limitation, the existence, validity, performance, or breach hereof.

11

8. If and for so long as any provision of this Agreement shall be deemed to be judged invalid for any reason whatsoever, such invalidity shall not affect the validity or operation of any other provision of this Agreement except only so far as shall be necessary to give effect to the construction of such invalidity, and any such invalid provision shall be deemed severed from this Agreement without affecting the validity of the balance of this Agreement.

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their duly authorized representatives effective as of the date first set forth above.

OPERATOR	VESSEL OWNER
[INSERT NAME OF OPERATOR]	[INSERT NAME OF VESSEL OWNER]
By:	By:
Title:	Title:
	As owner of the [Name of Vessel]
	Registration No. [                     ]
	State of Registry [                     ]

12

EX-10.4

Exhibit 10.4

SCHEDULE D-1

CHANGE ORDER FORM

PROJECT NAME: Sabine Pass LNG Receiving, Storage and Regasification Terminal	CHANGE ORDER NUMBER: SP/BE- 044
	DATE OF CHANGE ORDER: March 26, 2007
OWNER: Sabine Pass LNG, L.P.	Bundle of Changes #7 – (A) Manual (Craft) Wage and Per Diem Rate Increases; (B) LNG Berth Aides – CCTV Installation (C) Nitrogen Snuffing System Revision; (D)
CONTRACTOR: Bechtel Corporation
DATE OF AGREEMENT: December 18, 2004	Reduction of CEMS Scope

The Agreement between the Parties listed above is changed as follows:

A. Trend T-5017 - Compensation Package for manual (craft) labor wage increase

The current craft wages established pursuant to Change Order Number SP/BE-0032 dated May 16, 2006 are not sufficient to attract and retain qualified craft and supervision personnel to achieve the Ready for Cool Down dates, the Target Bonus date and the Forecasted Substantial Completion date. Effective March 5, 2007, the Parties have agreed to adjust its compensation package for manual (craft) labor as follows:

• Wage increase ($1,950,000)

• $1.00/hour increase to civil craft (journeyman) rate

• $3.00/hour increase to steel, mechanical, piping, electrical and instrument craft rate

• Adjustment to taxes and insurance (payroll adds) ($741,000)

• Increase Per Diem by $10/day for qualified workers ($934,000)

The total forecasted increase with respect to the above adjustments is $3,625,000 (“Re-revised Compensation”). In the event Contractor does not pay out the full Re-revised Compensation, the contract price will be adjusted by a separate Change Order to reflect the difference between the amount forecasted herein and the amount paid for manual labor.

All other terms and conditions of Change Order Number SP/BE-0032 shall remain in full force and effect.

B. Trend T-1014 – Supply and Installation of closed-circuit television (CCTV)

The CCTV cameras installation is to allow the Master and Pilot on the bridge of a docking LNG carrier to be able to monitor the water area immediately astern of the backing vessel. Weatherproof CCTV security cameras are to be installed at each of the two berths (N/W berth and S/E berth) in the vicinity of the rear-most mooring dolphin at each berth. Specific requirements were defined pursuant to Correspondence Number SP-BC-C-193 dated June 28, 2006 attached hereto.

The total cost of the CCTV is $72,481.

C. Trend T-1016 – Nitrogen Snuffing System for LNG Storage Tank Relief Valves

Contractor will supply each PSV tailpipe with a means to provide an individual dedicated burst of nitrogen for effective snuffing of fires. The Parties agreed solution is to replace one 3” control valve with four 1-1/2” control valves. Reference attached P&ID M6-24-00212 for detailed specifications. The total cost for this scope change is $54,672.

D. Trend T-1061 – Scope Reduction for Continuous Emissions Monitoring System (CEMS)

The Parties have agreed that CEMS equipment will not be installed. However, Contractor will complete the procurement process through shipment of the CEMS equipment to a designated warehouse and perform the necessary engineering to reflect this scope reduction. The cost savings from deleting the installation is offset by home office engineering costs to accommodate the change.

1 of 4

The Total estimated amount for this scope change is $0.

REFERENCE DOCUMENTS:

A-1)	Bechtel Letter SDN-25027-001-T-07-GAM-00019 dated February 27, 2007	$	3,625,000
A-2)	Change Order Number SP/BE-0032 dated May 16, 2006
B-1)	Estimate for CCTV In Vicinity Of Rear-Most Mooring Dolphin At Each Jetty (T-1014)	$	72,481
B-2)	Payment Milestones for CCTV In Vicinity Of Rear-Most Mooring At Each Jetty (T-1014)
B-3)	SPLNG Correspondence Number SP-BC-C-193 dated June 28, 2006
C-1)	Estimate Nitrogen Snuffing System Revision (T-1016)	$	54,672
C-2)	Payment Milestones Nitrogen Snuffing System Revision (T-1016)
C-3)	SPLNG Correspondence Number SP-BC-C-198 dated July 28, 2006
D-1)	SPLNG Correspondence Number SP-BE-C-239	$	0.00
D-2)	Bechtel Letter SDN-25027-001-T-07-GAM-00023 dated March 13, 2007
Change Order No. SP/BE-0044 TOTAL:		$	3,752,153

Page 2 of 4

SCHEDULE D-1

CHANGE ORDER FORM

PROJECT NAME: Sabine Pass LNG Receiving, Storage and Regasification Terminal	CHANGE ORDER NUMBER: SP/BE- 044
	DATE OF CHANGE ORDER: March 26, 2007
OWNER: Sabine Pass LNG, L.P.	Bundle of Changes #7 – (A) Manual (Craft) Wage and Per Diem Rate Increases; (B) LNG Berth Aides – CCTV Installation (C) Nitrogen Snuffing System Revision; (D)
CONTRACTOR: Bechtel Corporation
DATE OF AGREEMENT: December 18, 2004	Reduction of CEMS Scope

Adjustment to Contract Price

The original Contract Price was	$	646,936,000
Net change by previously authorized Change Orders (#SP/BE-002 to 028, 031, 033 thru 035; 037 thru 043)	$	123,382,703
The Contract Price prior to this Change Order was	$	770,318,703
The Contract Price will be increased by this Change Order in the amount of	$	3,752,153
The new Contract Price including this Change Order will be	$	774,070,856

Adjustment to dates in Project Schedule

The following dates are modified:

The Target Bonus Date will be unchanged.

The Target Bonus Date as of the date of this Change Order therefore is April 3 2008 (1,095 Days following the NTP)

The Guaranteed Substantial Completion Date will be unchanged and is December 20, 2008.

The Guaranteed Substantial Completion Date as of the date of this Change Order therefore is 1,355 days following NTP.

Adjustment to other Changed Criteria: Not Applicable

Adjustment to Payment Schedule:

A) Re-revised Compensation for Manual (Craft) Labor wage increase

Owner agrees to pay Contractor the Re-revised Compensation amount in three (3) equal payments that will be due and payable on June 30, 2007, October 31, 2007 and February 28, 2008.

B) See attached Payment Milestones for CCTV In The Rear-Most Mooring Dolphins at Each Jetty (T-1014);

C) See attached Payment Milestones for Revision to the Nitrogen Snuffing System (T-1016).

D) Not Applicable

Adjustment to Minimum Acceptance Criteria: No Change

Adjustment to Performance Guarantees: No Change

Adjustment to Design Basis: No Change.

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: No Change

This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change as described in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change.

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

Page 3 of 4

SCHEDULE D-1

CHANGE ORDER FORM

PROJECT NAME: Sabine Pass LNG Receiving, Storage and Regasification Terminal	CHANGE ORDER NUMBER: SP/BE- 044
	DATE OF CHANGE ORDER: March 26, 2007
OWNER: Sabine Pass LNG, L.P.	Bundle of Changes #7 - (A) Manual (Craft) Wage and Per Diem Rate Increases; (B) LNG Berth Aides - CCTV Installation (C) Nitrogen Snuffing System Revision; (D)
CONTRACTOR: Bechtel Corporation
DATE OF AGREEMENT: December 18, 2004	Reduction of CEMS Scope

/s/ Stan Horton	/s/ C. Asok Kumar
* Charif Souki
Chairman	Contractor
	C. Asok Kumar
	Name
	Project Director
	Title
4/18/07	4/30/07
Date of Signing	Date of Signing
/s/ Stan Horton
* Stan Horton
President & COO Cheniere Energy
4/18/07
Date of Signing
/s/ Ed Lehotsky
* Ed Lehotsky
Owner Representative
April 17, 2007
Date of Signing

* Required Owner signature – Mr. Horton may sign on behalf of Mr. Souki during Mr. Souki’s absence.

Page 4 of 4

SCHEDULE D-1

CHANGE ORDER FORM

PROJECT NAME: Sabine Pass LNG Receiving, Storage and Regasification Terminal	CHANGE ORDER NUMBER: SP/BE- 045
	DATE OF CHANGE ORDER: March 27, 2007
OWNER: Sabine Pass LNG, L.P.	Bundle of Changes #8 – (A) Phase 1 Critical Piping Tie-Ins; (B)
	Capital Assets Register as of November 30, 2006.
CONTRACTOR: Bechtel Corporation
DATE OF AGREEMENT: December 18, 2004

The Agreement between the Parties listed above is changed as follows:

A. Trend T-1022 Implement Owner’s unilateral Change Order SP/BE-036 dated September 14, 2006 for Phase 1 Critical Piping Tie-Ins. This Change Order supersedes Owner’s unilateral Change Order SP/BE-036 previously issued.

Summary Description of Change: Perform engineering, procurement, fabrication, shipping, storage, construction installation, and all other work necessary to achieve completed configurations for an additional six (6) critical piping tie-ins to the existing Phase 1 piping structure.

Tie-In	Function
2453 & 2454	LNG from the Phase 1 Header to the Phase 2 Tanks (S-104/105/106).
2455	Natural Gas from the Phase 2 BOG header to the Phase 1 BOG compressor.
2551	LNG from storage tanks to vaporizers (two way exchange Phase1/Phase2)
2552	Produced Natural Gas to Send-Out Metering Station
3356	Firewater from Phase 1 Booster Pumps to Phase 2 LNG Tank Monitors

B. Trend T-1058 Provide a project capital asset register for information available as of November 30, 2006.

The capital asset register will allocate the contract value as of November 2006 by equipment tag number and in some cases specific facilities, (i.e. marine facility, construction dock, roads, etc.) according to the agreed format. A total of 100 field non-manual hours is estimated to complete the work. Twenty (20) field non-manual hours are included as part of the total 100 hour budget for the purpose of answering questions and performing minor rework.

REFERENCE DOCUMENTS:

A-1)	Estimate for Critical Piping Tie-Ins (T-1022)	$	5,164,616
A-2)	Payment Milestones for Critical Piping Tie-Ins (T-1022)
A-3)	Unilateral Change Order Number SP/BE-036 Critical Piping Tie-Ins
B-1)	Estimate for Project Capital Asset Deliverable (T-1058)	$	11,330
B-2)	Payment Milestones for 11/30/06 Capital Asset Deliverable (T-1058)
Change Order SP/BE-045 TOTAL:		$	5,175,946

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SCHEDULE D-1

CHANGE ORDER FORM

PROJECT NAME: Sabine Pass LNG Receiving, Storage and Regasification Terminal	CHANGE ORDER NUMBER: SP/BE- 045
	DATE OF CHANGE ORDER: March 27, 2007
OWNER: Sabine Pass LNG, L.P.	Bundle of Changes #8 – (A) Phase 1 Critical Piping Tie-Ins; (B)
	Capital Assets Register as of November 30, 2006.
CONTRACTOR: Bechtel Corporation
DATE OF AGREEMENT: December 18, 2004

Adjustment to Contract Price

The original Contract Price was	$	646,936,000
Net change by previously authorized Change Orders (#SP/BE-002 to 028, 031, 033 thru 035; 038 thru 044)	$	127,134,856
The Contract Price prior to this Change Order was	$	774,070,856
The Contract Price will be increased by this Change Order in the amount of	$	5,164,616
The new Contract Price including this Change Order will be	$	779,235,472

Adjustment to dates in Project Schedule

The following dates are modified:

The Target Bonus Date will be unchanged.

The Target Bonus Date as of the date of this Change Order therefore is April 3 2008 (1,095 Days following the NTP)

The Guaranteed Substantial Completion Date will be unchanged and is December 20, 2008.

The Guaranteed Substantial Completion Date as of the date of this Change Order therefore is 1,355 days following NTP.

Adjustment to other Changed Criteria: Not Applicable

Adjustment to Payment Schedule: See attached “Payment Milestone – Critical Piping Tie-Ins (T-1022) and Project Capital Asset Register Deliverable (T-1058).

Adjustment to Minimum Acceptance Criteria: No Change

Adjustment to Performance Guarantees: No Change

Adjustment to Design Basis: No Change.

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: No Change

This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change as described in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change.

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

Page 2 of 4

SCHEDULE D-1

CHANGE ORDER FORM

PROJECT NAME: Sabine Pass LNG Receiving, Storage and Regasification Terminal	CHANGE ORDER NUMBER: SP/BE- 045
	DATE OF CHANGE ORDER: March 27, 2007
OWNER: Sabine Pass LNG, L.P.	Bundle of Changes #8 – (A) Phase 1 Critical Piping Tie-Ins; (B)
	Capital Assets Register as of November 30, 2006.
CONTRACTOR: Bechtel Corporation
DATE OF AGREEMENT: December 18, 2004

/s/ Stan Horton	/s/ C. Asok Kumar
* Charif Souki
Chairman	Contractor
	C. Asok Kumar
	Name
	Project Director
	Title
4/18/07	4/30/07
Date of Signing	Date of Signing
/s/ Stan Horton
* Stan Horton
President & COO Cheniere Energy
4/18/07
Date of Signing
/s/ Ed Lehotsky
* Ed Lehotsky
Owner Representative
April 17, 2007
Date of Signing

* Required Owner signature – Mr. Horton may sign on behalf of Mr. Souki during Mr. Souki’s absence.

Page 3 of 4

EX-10.5

Exhibit 10.5

Cheniere Energy, Inc.

Summary of Compensation for Executive Officers

The executive officers of Cheniere Energy, Inc. (“Cheniere”) are “at will” employees and, except as noted below, none of them has an employment or severance agreement, other than as provided under the Cheniere Energy, Inc. Amended and Restated 2003 Stock Incentive Plan.¹ The unwritten arrangements under which Cheniere’s executive officers are compensated include:

• a salary, reviewed annually by the Compensation Committee of the Board of Directors of Cheniere;

• eligibility for a discretionary annual cash bonus, as determined by the Compensation Committee;

• eligibility for awards under Cheniere’s Amended and Restated 2003 Stock Incentive Plan, as determined by the Compensation Committee;

• health, life, disability and other insurance and/or benefits; and

• vacation, paid sick leave and all other employee benefits.

The following table sets forth the 2007 annual base salary for each of Cheniere’s executive officers:

Executive Officer	2007 Annual Base Salary
Charif Souki Chairman and Chief Executive Officer	$	577,500
Stanley C. Horton President and Chief Operating Officer	$	446,250
Walter L. Williams Vice Chairman	$	262,500
Don A. Turkleson Senior Vice President and Chief Financial Officer	$	262,500
Keith M. Meyer Senior Vice President, Marketing	$	262,500
Jonathan S. Gross Senior Vice President, Exploration	$	262,500
Zurab S. Kobiashvili Senior Vice President and General Counsel	$	262,500

¹ Jean Abiteboul, located in our French office, has an employment agreement with a subsidiary of Cheniere. The agreement is for an unlimited term and may be terminated by the subsidiary or Mr. Abiteboul upon three months prior notice. The agreement provides for compensation substantially similar to the arrangements described above for Cheniere’s other executive officers.

Stuart J. Wagner Senior Vice President – Corporate Development	$	262,500
David B. Gorte Senior Vice President and Chief Risk Officer	$	262,500
Jean Abiteboul Executive Director, Cheniere LNG Services, S.A.R.L.	$	291,126	2
Robert K. Teague Vice President – Pipeline Operations	$	200,000

² Represents the US dollar equivalent of 220,500 euros based on an exchange rate of 1.3203 as of December 31, 2006.

EX-10.6

Exhibit 10.6

AMENDED AND RESTATED

SHAREHOLDERS AGREEMENT

By and between

Mercuria Energy Holding B.V.,

And

Cheniere LNG Services, Inc.

Being the Shareholders of

J & S Cheniere S.A., in Nyon, Switzerland

(the “Company”)

TABLE OF CONTENTS

			PAGE
AMENDED AND RESTATED SHAREHOLDERS AGREEMENT			3
ARTICLE 1 DEFINITIONS			3
	Section 1.1	Definitions	3
	Section 1.2	Currency	6
ARTICLE 2 SHAREHOLDING, BUDGETS, CONTRIBUTIONS AND DISTRIBUTIONS			6
	Section 2.1	Shareholding	6
	Section 2.2	Conversion into SARL	7
	Section 2.3	Budgets, Contributions and Capital	7
	Section 2.4	Distributions	8
ARTICLE 3 RESTRICTIONS ON TRANSFERS, ISSUANCES, REPURCHASES OR OTHER CHANGES IN THE STOCK			9
	Section 3.1	General Restrictions	9
	Section 3.2	Option to Purchase Shares	9
	Section 3.3	Attempted Transfers Void	11
	Section 3.4	After-Acquired Shares	11
ARTICLE 4 CHANGE OF CONTROL			11
	Section 4.1	Change of Control of Cheniere	11
ARTICLE 5 COMPANY MANAGEMENT			12
	Section 5.1	Board of Directors	12
	Section 5.2	Officers and Employees	13
	Section 5.3	Accounting and Compliance	14
ARTICLE 6 SHAREHOLDER’S COMPANY MEETINGS			16
	Section 6.1	Place of Meetings	16
	Section 6.2	Call of Meetings	16
	Section 6.3	Notice of Meetings of Shareholders	16
	Section 6.4	Manner of Giving Notice	16
	Section 6.5	Quorum; Voting	16
	Section 6.6	Proxies	16
ARTICLE 7 REPRESENTATIONS OF THE SHAREHOLDERS			16
	Section 7.1	Investment Intent	16
	Section 7.2	Unregistered Stock	17
	Section 7.3	Representations and Warranties	17
ARTICLE 8 MISCELLANEOUS PROVISIONS			19
	Section 8.1	Notices	19
	Section 8.2	Assistance of the Company by the Shareholders	19
	Section 8.3	Governing Law	20
	Section 8.4	Entirety; Amendments	20
	Section 8.5	Waiver	21
	Section 8.6	Severability	21
	Section 8.7	Captions, References	21
	Section 8.8	Jurisdiction	21
	Section 8.9	Binding Effect; Assignment	21
	Section 8.10	No Further Relationship	21
	Section 8.11	No Third-Party Beneficiaries	22
	Section 8.12	Counterparts	22

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AMENDED AND RESTATED

SHAREHOLDERS AGREEMENT

This Amended and Restated SHAREHOLDERS AGREEMENT (“Agreement”) is entered into effective as of May 8, 2007 (the “Effective Date”) by and among:

1. Mercuria Energy Holding B.V., a Netherlands corporation, of Koningslaan 112, 3583 GV Utrecht, Netherlands (“Mercuria”); and

2. Cheniere LNG Services, Inc., a Delaware corporation, of 717 Texas Avenue, Suite 3100, Houston, Texas 77002 United States of America (“Cheniere”).

being the sole shareholders of:

J & S Cheniere S.A., a Swiss corporation (société anonyme), or if applicable as set out below, a Swiss limited liability company (SARL), of Route de Saint-Cergue 9, P.O. Box 1216, 1260 Nyon, Switzerland (the “Company”).

WHEREAS, effective December 23, 2003, the Company, j&s Group S.A. and Cheniere LNG Services, Inc. entered into an original Shareholders Agreement with, and as the sole shareholders of, the Company;

WHEREAS, J&S Group S.A. (“J&S Group”) subsequently transferred, with the approval of Cheniere, its entire ownership in its shares of the Company Stock and its right, title and interests under the original Shareholder Agreement to J&S Energy Holding B.V. (“J&S Holding”), a subsidiary of J&S Group;

WHEREAS, J&S Energy Holding B.V. has been renamed Mercuria Energy Holding B.V.;

WHEREAS, Cheniere, as soon as practicable after the effectiveness of this Agreement, will transfer to Cheniere International Investments, B.V. (“Cheniere BV”), an affiliate of Cheniere, its entire ownership in its shares of the Company Stock and its right, title and interests hereunder, and Mercuria acknowledges and approves such assignment and transfer;

WHEREAS, upon effectiveness of this Agreement, the original Shareholders Agreement is terminated which is also acknowledged by the Company by way of executing this Agreement to that end;

WHEREAS, as the sole shareholders of the Company, Mercuria and Cheniere desire to change the legal form of the Company into a Swiss limited liability company (SARL) and to enter into this Agreement to amend and restate in full the original Shareholders Agreement;

NOW THEREFORE, in consideration of the mutual promises set forth herein and for other good and valuable consideration the receipt and sufficiency of which are hereby acknowledged the parties agree as follows:

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Article 1

Definitions

Section 1.1 Definitions As used in this Agreement, the following terms shall have the following meanings:

“Act” means the Swiss Code of Obligations dated 30 March 1911, as it may be amended from time to time.

“Affiliate” (including the terms “Affiliated” and “Affiliated with”) means, with respect to any Person: (i) any other Person, directly or indirectly, through one or more intermediaries, controlling, controlled by, or under common control with such Person; (ii) any other Person with respect to which such Person possesses the right to exercise, directly or indirectly, through one or more intermediaries, forty percent (40%) or more of the voting rights attributable to the ownership interests of such other Person; or (iii) any other Person with respect to which such Person is entitled to receive, directly or indirectly, through one or more intermediaries, forty percent (40%) or more of all dividends or distributions, as applicable, paid by such Person. As used in the preceding sentence, the term “control” (including the terms “controlling”, “controlled by” or “under common control with”) means the possession, directly or indirectly, through one or more intermediaries, of the power to direct or cause the direction of the management or policies of a Person, whether through the ownership of voting securities, by contract or otherwise.

“Agreement” means this Amended and Restated Shareholders Agreement of the Company, as amended and in effect from time to time.

“Articles of Incorporation” means the articles of incorporation of the Company, as they may be amended from time to time.

"Board of Directors" has the meaning set forth in Section 2.3(c) hereof.

“Business” has the meaning set forth in Section 7.3(a)(i) hereof.

“Business Day” means any day other than a Saturday, a Sunday or other day on which commercial banks in the Canton of Vaud, Switzerland, Larnaca, Cyprus and Houston, Texas are authorized or required to close under applicable laws.

“Buyout” has the meaning set forth in Section 3.2(b) hereof.

“Buyout Notice” has the meaning set forth in Section 3.2(b) hereof.

“Cash Available for Distribution” means, as of any date, and in each instance as proposed by the Board of Directors and, if and to the extent required under the Act or the Articles of Incorporation, decided by the Shareholders' meeting of the Company in its conclusive and sole discretion, the amount equal to the remainder of: (i) all Company cash and cash equivalents; minus (ii) all amounts to be retained to fund expenses, capital investments and other expenditures then owing or committed to by the Company, and further; minus (iii) all amounts to be retained to fund further reserves that may be necessary or appropriate; provided, however, that the respective distribution and/or, as the case may be; repayment of Shareholder Loans complies with the relevant provisions of the Act, the Articles of Incorporation and this Agreement.

“Change of Control” means, with respect to Cheniere Energy, either one of the following: (i) the date on which the Incumbent Directors cease to constitute a majority of the Board of Directors of Cheniere

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Energy; or (ii) the date on which any Person acquires more than forty percent (40%) of the outstanding voting common stock of Cheniere Energy, other than with the consent of the Board of Directors of Cheniere Energy; or (iii) the date on which Cheniere Energy is merged or consolidated with another entity and, as a result of such merger or consolidation, fifty percent (50%) or less of the outstanding voting securities of the surviving or resulting entity is owned directly or indirectly in the aggregate by the holders of the outstanding voting securities of Cheniere Energy immediately prior to such merger or consolidation.

“Cheniere BV” has the meaning set forth in the recitals hereto.

“Cheniere Energy” means Cheniere Energy, Inc., a Delaware corporation, the ultimate parent of Cheniere.

“Company” means J & S Cheniere S.A., a Swiss corporation (société anonyme), or, if applicable, a Swiss limited liability company (SARL).

“Contribution” has the meaning set forth in Section 2.3(d) hereof.

“2006 Financial Statements” has the meaning set forth in Section 7.3(a)(vi) hereof.

“Effective Date” has the meaning set forth in the preamble hereto.

“Governmental Authority” means each nation, state, kingdom, department, region, province, county, canton, municipality or other political subdivision, and any agency, authority, court, department, commission, board, bureau or instrumentality of any of them.

“Incumbent Directors” means Persons constituting the Board of Directors of Cheniere Energy on the Effective Date and any Person becoming a director of Cheniere Energy after the Effective Date whose election or nomination is (or was) approved in advance by a vote of at least a majority of the Incumbent Directors or whose nomination for election is (or was) approved in advance by a nominating committee composed of Incumbent Directors.

“Initiating Shareholder” has the meaning set forth in Section 3.2(b) hereof.

“LNG Business Opportunities” has the meaning set forth in Section 5.2(d) hereof.

“Offer” means a bona fide written cash purchase offer from a third-party purchaser who is not an Affiliate of the seller, which offer is payable fully in cash and not seller-financed and is otherwise in compliance with the requirements of Section 3.2(a).

“Offering Shareholder” has the meaning set forth in Section 3.2(a) hereof.

"Officers" has the meaning set forth in Section 5.1(b) hereof.

“Person” means any individual, general or limited partnership, corporation, limited liability company, executor, administrator or estate, association, trustee or trust or other entity.

“Pre-existing Loan” means the principal amount of the loan from Mercuria or its predecessors to the Company outstanding immediately prior to the Effective Date (computed without interest), in an amount not to exceed USD $15.9 million and the repayment of which is waived pursuant to Section 2.1(a).

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“Requirements of a Governmental Authority” means any law, statute, common law obligation, ordinance, order, requirement, restriction, rule, writ, injunction, decree, demand or regulation of or imposed by a Governmental Authority.

“Responding Shareholder” has the meaning set forth in Section 3.2(b) hereof.

“Response Notice” has the meaning set forth in Section 3.2(b) hereof.

“Sale Notice” has the meaning set forth in Section 3.2(a) hereof.

“SEC” has the meaning set forth in Section 5.3(a)(i) hereof.

“Shareholders” means, collectively, Mercuria and Cheniere.

“Shareholder Loans” means shareholder loans, which might be subordinated from time to time, made to the Company by the Shareholders, the repayment terms of which shall be duly approved by the Board of Directors of the Company.

“Shares” means those shares of Stock held by Mercuria and Cheniere on the Effective Date.

“Special Distributions” has the meaning set forth in Section 3.2(b)(i) hereof.

“Stock” means all of the outstanding shares of capital stock of the Company, in the form of a SA or, if applicable, a SARL.

“Transfer” means any assignment, transfer or other disposition (whether voluntarily, involuntarily or by operation of law).

“US GAAP” has the meaning set forth in Section 5.3(a)(i) hereof.

Section 1.2 Currency

Subject to any express provisions in this Agreement to the contrary, all payments, advances and contributions of capital to be made by a Shareholder to or on behalf of the Company or any other Shareholder shall be made in lawful money of the United States of America, which shall at the time of payment be legal tender for payment of all debts and dues, public and private and in funds available for immediate credit to the recipient’s account. The books and records of the Company shall be maintained in Swiss Francs in accordance with Swiss law and regulations.

Article 2

Shareholding, Budgets, Contributions and Distributions

Section 2.1 Shareholding

(a) Mercuria shall ensure that, not later than and as of the Effective Date, the Company’s net equity shall be equal to at least CHF 100,000 (one hundred thousand Swiss Francs). To that end, Mercuria shall, in particular, release the Company from, and waive, (i) the Pre-existing Loan, (ii) any accrued interest on the Pre-existing Loan, and (iii) any other amounts otherwise advanced or loaned to the Company by Mercuria or its predecessors, in each case outstanding immediately prior to the Effective Date, in view of the financial reorganization of the Company.

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(b) Mercuria shall indemnify, and hold harmless, Cheniere if and to the extent that the net equity of the Company, as of the Effective Date, does not amount to CHF 100,000 (one hundred thousand Swiss Francs). In addition, taxes, if any, arising from the recapitalization measure(s) shall be borne by the Company and the requirements for CHF 100,000 of net equity shall apply to the Company after payment of any such taxes.

(c) The total number of Shares outstanding as of the Effective Date consists solely of one hundred (100) Shares of par value CHF 1,000 (one thousand Swiss Francs) each. With effect as of the Effective Date, Mercuria hereby agrees to transfer and convey to Cheniere, in exchange for CHF 29,000 (twenty nine thousand Swiss Francs), twenty-nine (29) Shares of the Company, free of all liens, claims and encumbrances, so that Mercuria will have sole ownership and control of fifty-one (51) Shares and Cheniere will have sole ownership and control of forty-nine (49) Shares. Mercuria agrees to execute such documents of transfer concurrent with the execution of this Agreement and take such additional actions as may be required to convey the afore-mentioned twenty nine (29) Shares of the Company to Cheniere with effect as of the Effective Date.

Section 2.2 Conversion into SARL

The Shareholders undertake to initiate and take, and cause their representatives on the Board of Directors to initiate and take, all actions as may be reasonably necessary to convert the Company into a SARL pursuant to the Swiss Merger Act as soon as practicable. At the request of Cheniere, the Shareholders agree to cause the Company to make certain elections under Section 301.77701-2 of the regulations to United States Internal Revenue Code of 1986, as amended.

Section 2.3 Budgets, Contributions and Capital

(a) Attached as Exhibit 2.3 is a copy of the budget for calendar year 2007 (which includes the advance by each Shareholder in the form of a Shareholder Loan in the amount of USD 25 million) which budget is hereby approved by the Shareholders. Subsequent annual budgets will be approved in accordance with the provisions of Section 5.2(c). If the Shareholders' approval of an annual budget is required in accordance with Section 5.2(c), within thirty (30) Business Days after such Shareholder approval, each Shareholder shall each make a Contribution to the Company, on a pro-rata basis, in accordance with Section 2.3(d) below

(b) Within seven (7) Business Days after the Effective Date, Mercuria and Cheniere shall take, and shall each cause their representatives on the Board of Directors to take, the following action:

(i) each of Cheniere and Mercuria shall advance to the Company, in the form of a Shareholder Loan, the amount of USD 25 million, in immediately available funds, for the sole purpose of funding the obligations relating to the time charters of the two K-Line LNG vessels. The combined USD 50 million Shareholder Loans will be used to collateralize the required letter of credit under the existing agreements with K-Line;

(ii) the Parties acknowledge and agree that their respective Shareholder Loans made pursuant to Clause (i) above shall be returned to Cheniere and Mercuria upon the satisfaction of all the obligations under the time charter agreements with K-Line. The provisions of Section 2.4 shall not apply to repayments of the Shareholder Loans under this Section 2.3(ii).

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The Shareholders agree to promptly enter into appropriate note or loan agreements, bearing market rates of interest, to reflect the Shareholder Loans contemplated by this Section 2,3(b),

(c) If any LNG Business Opportunity, duly approved by the Company board of directors (the “Board of Directors”), or, if applicable, the authorized Officers of the Company) requires additional Company capital in the form of cash contributions, shareholder loans, guaranties, letters of credit or any other agreed form of financing contribution (beyond that provided in an approved annual budget), such LNG Business Opportunities and the related additional capital requirement shall be subject to the prior unanimous written approval of the Shareholders prior to the commitment to such LNG Business Opportunities.

(d) The Shareholders shall fund their respective approved monetary obligations pursuant to Section 2.3 in the form of any of the following, as may be mutually agreed (the “Contribution”): (i) cash contributions to the Company; (ii) subordinated Shareholder Loans on terms that are no less favorable to the Company then could be obtained from third-party sources; (iii) guaranties; (iv) standby letters of credit or other collateral; or (v) a combination of any of the foregoing.

(e) Each Shareholder shall be responsible for a portion of each component of such Contribution or any approved budget (other than the Shareholder Loans referred to in Section 2.3(b) on a pro-rata basis, based on the number of Shares owned. As of the Effective Date, such pro-rata sharing of each approved Contribution or budget is forty nine percent (49%) Cheniere and fifty one percent (51%) Mercuria. In the event a Shareholder fails to make its Contribution in accordance with this Section 2.3(e), the provisions of Section 3.2(b) shall apply.

Section 2.4 Distributions

(a) Cheniere and Mercuria agree that distributions of Cash Available for Distribution shall be made by the Company in the following priority:

(i) Mercuria shall be entitled to first receive a special distribution of dividend payments and/or, in the event of a liquidation of the Company, a special distribution of any liquidation proceeds on the Stock, held by Mercuria and Cheniere, until Mercuria has received an amount equal to the Pre-existing Loan;

(ii) upon the satisfaction of the requirements of clause (i) above, Cheniere shall be entitled to receive a special distribution of dividend payments and/or, in the event of a liquidation of the Company, a special distribution of any liquidation proceeds on the Stock, held by Mercuria and Cheniere, until Cheniere has received an aggregate gross amount of USD 10 million; and

(iii) upon satisfaction of clause (ii) above, all further Cash Available for Distribution shall be distributed to the Shareholders on a pro-rata basis, based on the number of Shares owned.

(b) In order to implement the special distributions as set out in Section 2.4(a): Cheniere assigns herewith its entitlements to future dividend payments and/or, in the event of a liquidation of the Company, to the special distribution of any liquidation proceeds from the Company on the Stock, held by Cheniere, to Mercuria (and Mercuria accepts herewith such assignment) until Mercuria has received, together with payments on Stock, held by Mercuria, an amount equal to the Pre-existing Loan; and Mercuria assigns herewith, upon the satisfaction of the requirements of clause (i) of Section 2.4(a), its entitlements to future dividend payments and/or, in the event of a liquidation of the Company,

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to the special distribution of any liquidation proceeds from the Company on the Stock, held by Mercuria, to Cheniere (and Cheniere accepts herewith such assignment) until Cheniere has received, together with payments on Stock, held by Cheniere, an aggregate gross amount of USD 10 million. Upon written request, each Shareholder agrees, as further evidence and assurance, to execute an appropriate dividend assignment agreement and related documents as may be reasonably requested by the other Shareholder to implement the contractual entitlements described in this Section 2.4 and to reclaim any Swiss withholding taxes levied on the payment of dividends or, as the case may be, of liquidation proceeds.

Article 3

Restrictions on Transfers, Issuances, Repurchases or Other Changes in the Stock

Section 3.1 General Restrictions

(a) No Shareholder may Transfer or otherwise directly or indirectly dispose of any Stock or any interest therein except pursuant to an Offer, and in the case of a Transfer pursuant to an Offer, such Transfer shall only be permitted after the Offering Shareholder has complied with all of the provisions of this Article 3, including, without limitation, making an offer to sell such Stock to the other Shareholder. For the avoidance of doubt, no partial Transfers of Shares shall be allowed.

(b) No Shareholder may directly or indirectly pledge, mortgage, hypothecate or otherwise encumber any of its Stock.

(c) The Company may not issue, repurchase, subdivide, combine or otherwise change in any manner the presently outstanding Stock of the Company without the unanimous written consent of the holders of all of the Stock.

(d) Subject to the provisions of Section 3.2, none of the Shareholders may Transfer or otherwise directly or indirectly dispose of any Stock unless the transferee: (i) first enters into a deed of adherence to be bound by all terms and conditions of this Agreement; and (ii) upon the closing of the Transfer of the Stock, steps into all Shareholder Loans, guaranties, standby letters of credit or other collateral granted to the Company for a portion equal to the number of Shares transferred divided by the total number of Shares outstanding.

(e) Mercuria hereby agrees to approve the Transfer of all of the Shares of the Company held by Cheniere to Cheniere BV, which Shares shall be held subject to the terms of this Agreement, and agrees to recognize Cheniere BV as Cheniere’s successor in interest for all purposes hereunder, without any further compliance with other provisions of this Article 3. All references to Cheniere in this Agreement shall refer to Cheniere BV from and after such transfer.

Section 3.2 Option to Purchase Shares

(a) If a Shareholder desires to sell all, but not less than all, of its Shares pursuant to an Offer (the “Offering Shareholder”), then the Offering Shareholder shall provide written notice (the “Sale Notice”) including all of the terms and conditions of such Offer (which must be to a single purchaser for an all cash purchase price payable in full at the time of purchase and under which the purchaser shall become a successor party to this Agreement in replacement of the Offering Shareholder at the time of purchase) to the other Shareholder, and the other Shareholder shall have the right and option (but no obligation) to purchase such Shares on the same terms and conditions as set forth in the Offer (subject, as to timing, to the further provisions of this Section 3.2). The other Shareholder’s option hereunder shall expire on the sixtieth (60th) day after receiving the Sale Notice from the Offering

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Shareholder. Such option shall be considered as exercised when notice in writing of exercise has been delivered addressed to the Offering Shareholder in accordance with Section 8.1, prior to its expiration. Upon the closing of the sale of the Shares to the other Shareholder or to the party that made the Offer, the purchaser shall deliver the purchase price to the Offering Shareholder in cash in accordance with the provisions of the Offer, and the Offering Shareholder shall deliver the certificate(s) representing the Stock to the purchaser, duly endorsed in blank for Transfer or accompanied by an appropriate stock power, or, if applicable, shall Transfer the stock by public deed or, as the case may be, by a deed in writing to the purchaser, together with all documents necessary for an effective Transfer and shall have affixed to such certificate, or, if applicable, such deed, all required stock transfer stamps, if any, or deposit with the Company at that time sufficient funds to pay for such stamps. The shares of Stock so delivered shall be free and clear of any and all liens, pledges, charges, security interests and other encumbrances other than as imposed by this Agreement. Upon the closing of a sale under this Section 3.2 of the Shares theretofore held by a Shareholder, this Agreement shall apply to the purchaser as successor to and in replacement of the Offering Shareholder fully as if the purchaser had been an original signatory hereto, and all obligations of the Offering Shareholder under this Agreement shall terminate.

(b) If a Shareholder (the “Initiating Shareholder”) desires, in accordance with the provisions of Sections 2.3(e), 3.2(c), or 5.1(a), to require either a sale of all of its Shares to the other Shareholder (the “Responding Shareholder”) or a purchase of all of the Responding Shareholder’s Shares (in either case, a “Buyout”), the Initiating Shareholder shall deliver to the Responding Shareholder in accordance with Section 8.1 a written notice (a “Buyout Notice”) setting forth in reasonable detail:

(i) the Initiating Shareholder’s evaluation of the current fair market value of the Stock, and the resulting current fair market value of each Share and the basis for such evaluation, excluding for purposes of this evaluation any special distributions provided for under clauses (i) and (ii) of Section 2.4 (“Special Distributions”); and

(ii) the Initiating Shareholder’s offer and commitment to sell its Shares to the Responding Shareholder or to purchase the Shares of the Responding Shareholder, as provided for in this Section 3.2(b).

Within sixty (60) days after receipt of a Buyout Notice, the Responding Shareholder must elect by delivering written notice (a “Response Notice”) to the Initiating Shareholder in accordance with Section 8.1 either (x) to sell its Shares to the Initiating Shareholder for the fair market value thereof set forth in the Buyout Notice or (y) to purchase the Shares of the Initiating Shareholder for the fair market value thereof set forth in the Buyout Notice. In the event that the Responding Shareholder fails to deliver timely a proper Response Notice, the Responding Shareholder shall be deemed to have elected to sell its Shares and to have accepted and agreed to the evaluation thereof by the Initiating Shareholder as set forth in the Buyout Notice. The purchase and sale of Shares, as selected by the Responding Shareholder in the Response Notice and at the price set forth by the Initiating Shareholder in the Buyout Notice, shall be closed within thirty (30) days after delivery of the Response Notice. Upon the closing of the sale of the Shares to the other Shareholder, whether under this Section 3.2(b) or Article 4, the purchaser shall deliver the purchase price in cash, and the seller shall deliver the certificate(s) representing the Shares to the purchaser, duly endorsed in blank for Transfer or accompanied by an appropriate stock power or, if applicable, shall transfer the Shares by public deed or, as the case may be, by a deed in writing to the purchaser, together with all documents necessary for an effective Transfer and shall have affixed to such certificate all required stock transfer stamps, if any, or deposit with the Company at that time sufficient funds to pay for such stamps. The Shares so delivered shall be free and clear of any and all liens, pledges, charges, security interests and other encumbrances.

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(c) Notwithstanding anything to the contrary contained herein, either Shareholder may initiate a Buyout and may effect a Buyout at any time in accordance with the provisions of Section 3.2(b). In the event both Shareholders initiate a Buyout, the Buyout of the Shareholder who first serves its Buyout Notice on the other shall prevail and control, as measured by the date and time of receipt of such Notice in accordance with Section 8.1.

(d) Except in the case of a sale upon a Change of Control in accordance with Article 4, if any of the Special Distributions provided for in clauses (i), and (ii) of Section 2.4 have not been completed, the remaining balance of the Special Distribution of the selling Shareholder shall remain as a liability of the Company and shall be repaid to the selling Shareholder out of the first cash distributions of the Company until the amount of the applicable Special Distribution has been fully settled by the Company. Each Party hereto acknowledges and agrees that it will be a condition of the purchase and sale of any shares of Stock under any provision of this Section 3.2 and Article 4 that the purchaser (which may be the other Shareholder) shall obtain a release and shall indemnify the selling Shareholder from any and all liabilities arising from any and all shareholder loans, guaranties, letters of credit or any other form of financing previously put in place by the selling Shareholder to collateralize or secure any obligations of the Company. Upon the occurrence of a Change of Control, the provisions of Article 4 shall apply.

Section 3.3 Attempted Transfers Void

Except as provided in this Article 3 or pursuant to Article 4, no Transfer or attempted Transfer of the Shares of any Shareholder or Transfer of any interest in the Shares, whether by absolute or by collateral assignment or otherwise, whether by gift or for valuable consideration, and no matter how conditioned, shall in any manner be effective or binding upon the other Shareholders or the Company, unless made in full compliance with the terms hereof or with the express written consent of all parties hereto.

Section 3.4 After-Acquired Shares

Whenever any Shareholder who is a party to this Agreement acquires additional Shares, such Shares so acquired shall be subject to all of the terms and provisions of this Agreement.

Article 4

Change of Control

Section 4.1 Change of Control of Cheniere

Within five (5) Business Days after a Change of Control that occurs while Cheniere and Mercuria continue to hold their respective forty nine (49) Shares and fifty one (51) Shares, Cheniere shall send a notice (the “Informational Notice”) to Mercuria setting forth a statement that a Change of Control has occurred. Mercuria shall thereafter have the right, but not the obligation, to purchase, in cash, the outstanding forty nine (49) Shares held by Cheniere at a price equal to the total contributions made to the Company by Cheniere, whether in the form of loans or cash advances, plus the portion of the USD 10 million Special Distribution remaining unpaid to Cheniere under this Agreement and further adjusted by Cheniere’s share of the undistributed amount of profits or losses incurred by the Company to date. The right to purchase the outstanding Shares held by Cheniere shall terminate ninety (90) days after the delivery of the Information Notice.

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In absence of such Information Notice, Mercuria shall be entitled to act as if such notice would have been received and shall have the right to deliver a Buyout Notice to Cheniere within ninety (90) Business Days following any public announcement under applicable SEC regulations.

Article 5

Company Management

Section 5.1 Board of Directors

(a) In accordance with Swiss laws and regulations, the holder of the fifty-one (51) Shares held by Mercuria as of the Effective Date shall have the right to appoint three (3) members to the Board of Directors of the Company, and the holder of the forty-nine (49) Shares held by Cheniere as of the Effective Date shall have the right to appoint three (3) members to the Board of Directors of the Company. All resolutions, appointments, decisions and other acts permitted or required to be effected by the Board of Directors shall be effective only if approved by: (a) unanimous affirmative vote of all six (6) members at a meeting duly convened; or (b) unanimous written consent of all six (6) members. In the absence of such unanimous approval, no act of the Board of Directors shall be effective. In the event that a stalemate occurs as to any matter proposed to be acted upon by the Board of Directors, the Shareholders may cause such stalemate to be resolved to their mutual accord by their appointed Directors, or else either Shareholder may initiate a Buyout proceeding in accordance with Section 3.2(b). All documents, contracts, commitments, liabilities and statements are not valid unless signed by two (2) Directors one of whom has been appointed by Mercuria and one of whom has been appointed by Cheniere. The Directors will elect one of themselves to serve as the Chairman of the Board of Directors who will chair all of the Board of Directors meetings and the Shareholders meetings.

(b) The Board of Directors shall be responsible for and have sole authority over the following business, decisions and acts of the Company:

(i) appointment of the officers, or if applicable, the managers (the "Officers") of the Company and delegations (or changes to delegations) of authority to the various Officers of the Company (each of Mercuria and Cheniere shall have the right but not the obligation to propose that employees of their respective companies be considered for secondment to the Company);

(ii) assignment and approval of risk levels and spending limits of the Company’s officers, employees and agents;

(iii) submission to Shareholders of LNG Business Opportunities;

(iv) proposal to the Shareholders of the amount, if any, of Cash Available for Distribution; and

(v) all other decisions, commitments, expenditures, contracts and business, decisions and acts of the Company other than: (x) those that are within the authorities of Officers of the Company that have already been expressly delegated by the Board of Directors; and (y) those that are immaterial in amount or significance and are approved by an appropriate Officer of the Company.

(c) Any other provisions of this Agreement to the contrary notwithstanding, in the event that any transaction, contract or other relationship is to be entered into between the Company, on the one hand, and a Shareholder or an Affiliate of a Shareholder, on the other

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hand, such transaction, contract or other relationship shall not be allowed, authorized or entered into until and unless unanimously approved by the Directors of the Company appointed by the Shareholder that is not (and whose Affiliates are not) proposing to enter into such transaction, contract or other relationship with the Company.

(d) Meetings of the Board of Directors shall be held at the offices of the Company or at such other place as is designated in the call of the meeting of the Board of Directors, provided that a Director may attend by telephone conference or similar communications equipment, in which case the physical presence of such Director is not necessary.

(e) Meetings of the Board of Directors may be called at any time by the Chairman upon the request of any Director for the purpose of taking action upon any matter requiring the vote or authority of the Board of Directors as provided in this Agreement or upon any other matter as to which such vote or authority is deemed by any Director to be necessary or desirable or to be required by applicable law. In any event, regular meetings of the Board of Directors shall be convened at least quarterly in accordance with a schedule fixed in advance by the Board of Directors.

(f) All notices of meetings of the Board of Directors shall be sent or otherwise given to each Director in accordance with Section 5.1(g) not less than five (5) Business Days, unless waived, before the date of the meeting. The notice shall specify: (i) the place, date, and hour of the meeting; and (ii) the general nature of the business to be transacted.

(g) Notice of any meeting of the Board of Directors shall be given personally or by telephone to each Director or sent by telecopy, electronic mail (or similar electronic means), or by an internationally recognized overnight courier, charges prepaid, addressed to the Director at the address of that Director or given by the Director for the purpose of notice. Notice shall be deemed to have been given at the time when delivered.

(h) At any meeting of the Directors, the presence of all six (6) Directors, in person, by telephone conference or similar communication equipment shall constitute a quorum for all purposes.

(i) Any action that may be taken at any meeting of the Board of Directors may be taken without a meeting if a consent in writing setting forth the action so taken is signed by all Directors. Any such written consent may be executed and given by facsimile or similar electronic means.

(j) The Shareholders agree that the Chairman of the Board of Directors shall not have a casting vote in the event of a tie vote of the Directors. The Company, as soon as practicable, shall hold an extraordinary Shareholders meeting to amend its articles of incorporation accordingly.

Section 5.2 Officers and Employees

(a) The Board of Directors may, from time to time, designate one or more Persons to be Officers of the Company. Any Officer so designated shall have such authority and perform such duties as the Board of Directors may, from time to time, delegate to such Officer.

(b) Subject to the approval rights described herein, the business and affairs of the Company shall be managed exclusively under the direction of the Board of Directors, or by or under the direction of one or more Officers pursuant to expressly delegated authority from the Board of Directors of the Company. The power to act for or to bind the Company shall be vested exclusively in the Board of

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Directors of the Company, subject to the Board of Directors’ authority to delegate powers and duties to Officers as set forth herein. Subject to the foregoing and to the extent so expressly delegated by the Board of Directors, the Officers shall have the power and authority to execute and deliver contracts, instruments, filings, notices, certificates, and other documents of whatsoever nature on behalf of the Company. The Officers of the Company shall have power and authority, as expressly delegated to them by the Board of Directors of the Company, to cause the Company to hire employees, except Officers appointed by the Board of Directors, and to cause the Company to pay such employees in their reasonable discretion.

(c) Prior to October 1 of each year during the term of this Agreement, the Officers of the Company shall prepare and submit to the Board of Directors for approval an annual budget for the following year. Notwithstanding anything to the contrary herein: if (i) the proposed annual budget as approved by the Board of Directors; or (ii) any proposed supplement to any annual budget or other Company expenditure authorization, requires, in either case, additional funding or any type of support from the Shareholders, such budget, supplement or expenditure authorization shall require the prior approval of the Shareholders.

(d) The Officers to whom such power and authority is expressly delegated by the Board of Directors shall have discretion to evaluate potential LNG related business opportunities for the Company (“LNG Business Opportunities”), including:

(i) chartering and operating LNG vessels;

(ii) obtaining capacity access to regasification terminals and to gas storage facility terminals;

(iii) subject to the prior written approval by the Shareholders of a risk management program and agreed monetary or liability limitations, trading and marketing of LNG and natural gas (including the related hedging of LNG and natural gas) in accordance with such program and limitations; and

(iv) entering into contracts pertinent to and in furtherance of the foregoing.

Upon such Officers’ selection of appropriate LNG Business Opportunities, they shall each time present in writing such LNG Business Opportunities to the Board of Directors for consideration as to whether the Company approves and determines to provide the financing necessary to undertake, perform and complete such LNG Business Opportunities, with such financing and/or capital Contribution decision being determined and unanimously agreed by all Shareholders in accordance with Section 2.3(c). Upon the written decision to finance a proposed LNG Business Opportunities, the Shareholders shall be obligated to provide and, in accordance with Section 2.3(c), continue to provide the financing therefore as so approved .

(e) The initial Officers their respective delegated authorities and approved risk levels and spending limits and the initially approved LNG Business Opportunities and related financial and other authorized commitments, if any, are set forth on Exhibit 5.2(e) attached to and included as part of this Agreement.

Section 5.3 Accounting and Compliance

(a) The Shareholders shall cause the Company to properly prepare and furnish to Cheniere and/or Mercuria, as applicable, at the Company’s expense:

(i) not less than fifteen (15) days prior to the date by which Cheniere Energy must file audited annual financial statements with the United States Securities and Exchange Commission (“SEC”), audited annual financial statements of the Company prepared in accordance with United States generally accepted accounting principles and applicable requirements of the SEC (“US GAAP”), and, if requested, separate audited statements prepared in accordance with International Financial Reporting Standards (“IFRS”), audited by an independent accounting firm registered with the Public Accounting Oversight Board and approved by the Shareholders;

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(ii) not later than fifteen (15) days prior to the date by which Cheniere Energy must file unaudited interim financial statements with the SEC, unaudited interim financial statements of the Company prepared in accordance with US GAAP and, if requested, separate financial statements prepared in accordance with IFRS;

(iii) not later than sixty (60) days after the Effective Date which is fifteen (15) days prior to the date by which Cheniere Energy must file audited historical financial statements and unaudited historical financial statements of the Company prepared in accordance with US GAAP, if applicable, as a result of any purchase by Cheniere of Shares of Company Stock (including, if applicable, the purchase of twenty-nine (29) Shares as of the Effective Date), such audited and unaudited historical financial statements of the Company prepared in accordance with US GAAP; and

(iv) not less than fifteen (15) days prior to the date by which Cheniere Energy must file any report or disclosure about the same with the SEC or other governmental authorities, any other information about the Company, its business, contracts, employees, liquidity, results of operations, and other matters required to be reported or disclosed by Cheniere to the SEC or other governmental authorities.

Cheniere will notify the Company, as soon as practicable, of the filing dates specified in clauses (i) through (iv) above.

(b) The Shareholders shall cause the Company, at its expense, to assist and cooperate with the Shareholders in complying with their respective applicable securities and other laws and regulations of the United States and elsewhere that may be applicable by reason of each Shareholder’s relationship with the Company, including but not limited to the Sarbanes-Oxley Act and the Foreign Corrupt Practices Act and the Internal Revenue Code of 1986, as amended, including the international boycott provisions therein.

(c) The Shareholders shall cause the Company to maintain its books, records and accounts in accordance with applicable Swiss law and regulations, in a format that will permit audit. It shall maintain its fiscal year as the calendar year. Each Shareholder shall have the right, at its expense, to audit the books and records of the Company, upon prior written notice to the Company and the other Shareholder, and the Company shall provide assistance, support and adequate work space to the auditors sent to perform any such audit.

(d) The Shareholders shall cause the Company, at its expense, to prepare (or have prepared) and timely file all required filings with the Swiss regulatory, governmental and taxing authorities and shall also assist and cooperate with the Shareholders, the Mercuria Group and Cheniere Energy, Inc. in complying with their respective tax filings as may be required in other relevant taxing jurisdictions, including the Netherlands, Cyprus and the United States of America.

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Article 6

Shareholder’s Company Meetings

Section 6.1 Place of Meetings

Meetings of Shareholders shall be held at the offices of the Company or at such other place as is designated by the Board of Directors.

Section 6.2 Call of Meetings

Meetings of Shareholders may be called at any time by the Chairman of the Board of Directors for the purpose of taking action upon any matter requiring the vote or authority of the Shareholders as provided in this Agreement or upon any other matter as to which such vote or authority is deemed by any Shareholder, or by the Board of Directors, to be necessary or desirable or to be required by applicable law. The Chairman of the Board of Directors shall call a meeting of the Shareholders upon the request of any Shareholder. In any event, meetings of the Shareholders shall not be more frequent than once per month.

Section 6.3 Notice of Meetings of Shareholders

All notices of meetings of Shareholders shall be sent to each Shareholder in accordance with the Act and Clause 11 of the Articles of Incorporation not less than twenty (20) days or more than ninety (90) days before the date of the meeting. The notice shall specify: (i) the place, date, and hour of the meeting; and (ii) the agenda and the proposals of the Board of Directors as well as those, if any, of the shareholders who requested the convening of the meeting or the inclusion of an item on the agenda. The notice of an ordinary general meeting of shareholders shall also mention that the management report and the auditor’s report are available for the shareholders at the registered office.

Section 6.4 Manner of Giving Notice

Notice of any meeting of Shareholders shall be sent to each Shareholder by registered mail or courier service.

Section 6.5 Quorum; Voting

At any meeting of the Shareholders, the presence of all Shareholders, in person or by proxy, shall constitute a quorum for all purposes.

Section 6.6 Proxies

Each Shareholder entitled to vote or act on any matter at a meeting of Shareholders shall have the right to do so by proxy, provided that an instrument authorizing such a proxy to act is executed by the Shareholder in accordance with articles 689b to 690 of the Act.

Article 7

Representations of the Shareholders

Section 7.1 Investment Intent

Each Shareholder hereby represents and warrants to the Company and the other Shareholder that such Shareholder has acquired its shares of Stock for such Shareholder’s own account, for investment

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purposes only and not with a view to the distribution or resale thereof, in whole or in part, and agrees that it will not Transfer, or offer to Transfer, all or any portion of its Stock in any manner that would violate, or cause the Company to violate, this Agreement or any applicable securities laws.

Section 7.2 Unregistered Stock

Each Shareholder hereby acknowledges that such Shareholder is aware that the Stock (and the offering, issuance and sale thereof to such Shareholder) has not been registered under any applicable securities laws. Each Shareholder further acknowledges that the Company will not, and has no obligation to, recognize any Transfer of all or any part of Stock to any Person except in accordance with this Agreement.

Section 7.3 Representations and Warranties

(a) Mercuria represents and warrants to Cheniere as of the Effective Date (except as indicated otherwise) that the following is complete, correct and not misleading:

(i) The Company is a corporation duly incorporated and validly existing under the laws of Switzerland, with the power and authority (corporate and other) to own its properties and conduct its business as currently conducted and intended to be conducted (such business hereinafter the “Business”).

(ii) Mercuria is duly authorized to enter into and perform its obligations under or in connection with this Agreement.

(iii) The entering into this Agreement and the performance thereof (a) do not breach or affect either wholly or partly the conditions of any of the contracts entered into by the Company or of the contracts to which the Company is subject to; (b) do not lead to the creation of any kind of rights of third parties or of encumbrances upon assets of the Company; (c) do not violate any court judgments or temporary restraining orders issued against Mercuria or the Company; and (d) do not lead to automatic termination of any contracts whatsoever entered into by the Company and do not lead to termination rights of the respective other party to the contract.

(iv) The obligations of Mercuria according to this Agreement are valid, binding and enforceable against it.

(v) There are no supplementary or side agreements between Mercuria and the Company except for this Agreement. Other than disclosed to the other party in writing, there are no intercompany or commercial agreements or similar agreements with, or with respect to, the Company, voting trusts, proxies, sub-participation agreements, silent participation agreements or other agreements or understandings with respect to the voting of any capital stock of, or any shares or interest in, the Company.

(vi) The audited financial statements of the Company for the year ending 31 December 2006 including the notes thereto (hereinafter referred to as the "2006 Financial Statements", attached as Exhibit 7.3(a)(vi)), have been established in compliance with legal provisions on accounting and with generally accepted accounting principles applied on a consistent basis, and such accounts truly reflect the assets, the equity and reserves, the financial condition and the profitability of the Company as of the date of the accounts. As of 31 December 2006, there have been no material claims or contingent claims of any kind (including

17

tax claims) against the Company which would have had to be shown, according to legal provisions and generally accepted accounting principles applied on a consistent basis, in the 2006 Financial Statements but in fact have not been shown in such accounts. Since 31 December 2006, the Business has been carried on in the orderly manner consistent with normal business operation consistent with past practice.

(vii) No governmental, administrative, regulatory, court, arbitration, or other proceedings are pending or, to the best of the Company's knowledge after reasonable and careful inquiry, threatened against the Company.

(viii) The Company has not any outstanding claims, liabilities or indebtedness, contingent or otherwise, whether of a contractual nature or for third party obligations, other than as set forth in the 2006 Financial Statements or referred to herein, other than liabilities of less than CHF 100,000, in the aggregate, incurred subsequent to the 2006 Financial Statements in the ordinary course of business consistent with past practice.

(ix) Exhibit 7.3(ix) attached hereto contains an accurate and complete list of the Company's entire agreements of a value exceeding CHF 100,000 and of all of the Company's agreements with its Shareholders as well as related person therewith, or the members of the Board of Directors. All such agreements are in full force and effect, and the Company is not in material or potential breach of any such agreement. The Company is not a party to any oral or written contract, arrangement, understanding, guaranty, commitment (whether in respect of capital expenditure or otherwise), which involves or could involve, singly or in the aggregate, an obligations or liabilities of CHF 100,000 or more. The Company has not entered into any agreement which requires or may require, or confers any right to require, the sale (whether for cash or otherwise) or the transfer by it of any asset or any securities of the Company. The Company is not a party to any consortium, partnership, un-incorporated association or profit sharing arrangement or agreement. The Company is not in default of any material agreement or arrangement to which it is a party.

(x) The Company has terminated all direct and indirect financial transactions, arrangements or relationships with Mr. Karim Souki, including, without limitation, that certain Consultancy Agreement dated March 1, 2004 between the Company and Investors Administration Services Limited.

(xi) The Company has filed all required Swiss Federal and Cantonal tax returns and those returns properly reflect the income or operating losses generated by the Company. The Company has operated its business in compliance with the terms of the Swiss Tax Ruling received from the Canton de Vaud on November 4, 2004.

(b) Cheniere represents and warrants to Mercuria as of the Effective Date (except as indicated otherwise) that the following is complete, correct and not misleading:

(i) Cheniere is duly authorized to enter into and perform its obligations under or in connection with this Agreement.

(ii) The obligations of Cheniere according to this Agreement are valid, binding and enforceable against it.

(iii) The entering into this Agreement and the performance thereof do not violate any court judgments or temporary restraining orders issued against Cheniere.

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(iv) There are no supplementary or side agreements between Cheniere and the Company except for this Agreement. Other than disclosed to the other party in writing, there are no intercompany or commercial agreements or similar agreements with, or with respect to, the Company, voting trusts, proxies, sub-participation agreements, silent participation agreements or other agreements or understandings with respect to the voting of any capital stock of, or any shares or interest in, the Company.

(c) If and to the extent that any representation or warranty set forth in Section 7.3 is breached, incorrect or incomplete in a material respect, the non-complying Party shall immediately, or at the latest within one month after request to this effect, remedy such situation. If a complete remedy is not possible or is not achieved within thirty (30) days of such request, the complying Party shall be compensated by the non-complying Party in cash for the damage suffered due to such breach. The damages shall be the difference in value of the Company’s assets between the represented and/or warranted status and the actual status in the Company or, if such a difference cannot reasonably be determined, the estimated amount of the costs incurred by the Company for bringing about the represented and/or warranted status.

(d) Claims according to this Section 7.3 are to be notified within two (2) months after the underlying facts become known to and fully appreciated by the party. The duty to examine and notify immediately (article 201 of the Act) shall not apply.

Article 8

Miscellaneous Provisions

Section 8.1 Notices

All notices provided for or permitted to be given pursuant to this Agreement must be in writing and shall be sent to or made at the addresses set forth on the signature pages hereto. Any notice given hereunder shall be effective: (a) if given by mail, ten (10) Business Days after depositing the same in the mail addressed to the party to be notified, postpaid and certified with return receipt requested; (b) if sent by express mail or overnight delivery, two (2) Business Days after such notice is sent, postage prepaid; (c) if sent by hand courier service, the day that such notice is delivered; (d) if sent by facsimile, prepaid telegram or telex, at the time that such communication is transmitted and the appropriate confirmation is received by the sender; or (e) if given by other means, when such notice is actually delivered to such party. By giving written notice thereof, each Shareholder shall have the right from time to time to change its address pursuant hereto.

Section 8.2 Assistance of the Company by the Shareholders

(a) The Shareholders acknowledge that the Company and Cheniere Marketing, Inc. (“Cheniere Marketing”): (i) are currently negotiating and propose to enter into an LNG sale and purchase agreement (substantially in the form of Exhibit 8.2(a) with such changes as may be mutually agreed) which will provide for the sale by the Company of up to approximately 200,000 mmbtu/d of LNG to Cheniere Marketing for delivery at the Sabine Pass LNG (such agreement as finally executed, the “SPA”); and (ii) propose to enter a new LNG sale and purchase agreement, substantially similar to the final form of the SPA, for the sale by the Company of up to an additional 200,000 mmbtu/d of LNG to Cheniere Marketing for delivery at the Cheniere’s Corpus Christi LNG receiving terminal. The final form of each SPA will only cover an annual quantity of 78,475,000 mmbtu (the “annual contract quantity”), and will contain a provision that in the event of the sale by either Shareholder of its entire interest in the Company (other than a sale contemplated under Section 4.1 of this Agreement), the Company under each SPA will automatically become contractually committed, on an annual basis, to

19

deliver to Cheniere Marketing the annual contract quantity (approximately 200,000 mmbtu/d) of LNG with delivered quantities priced in accordance with the existing pricing provisions contained Exhibit 8.2(a). The respective obligations of the above parties to enter into any of the agreements contemplated by this Section 8.2(a) shall terminate and be without further force and effect: (1) sixty (60) days after the Effective Date, with regard to the LNG sale and purchase agreement contemplated by clause (i) above, and (2), with regard to the agreement contemplated by clause (ii) above, sixty (60) days after receipt of written notification from Cheniere that the Corpus Christi LNG receiving terminal has been approved by the Federal Energy Regulatory Commission and all other approvals and permits have been received which are necessary for the commencement of the construction of such terminal.

(b) Upon execution of any of the agreements contemplated by Section 8.2(a) above, each Shareholder agrees that it and its majority owned affiliates will endeavor in good faith and use reasonable commercial efforts to assist and cooperate with the Company's efforts to obtain sufficient FOB cargoes of LNG to deliver approximately 200,000 mmbtu/d or 400,000 mmbtu/d, as applicable, of LNG to Cheniere Marketing in accordance with the agreements entered into pursuant to Section 8.2(a) above. The foregoing shall not limit Cheniere Marketing’s ability to fully utilize its reserved regasification capacity at any of Cheniere Energy’s applicable LNG receiving terminals in the event that the Company fails to schedule and deliver, on a ratable basis, in accordance with the agreements entered into pursuant to Section 8.2(a) above. The undertaking set forth Section 8.2(a) shall remain in effect during the up-to-10-year terms of (1) the 145,000 cm-capacity LNG vessel chartered by the Company in August 2004 from Kawasaki Kisen Kaisha, Ltd. ("K-Line") and (2) the 154,200 cm-capacity LNG vessel chartered by the Company in August 2004 from a joint venture company established by K-Line, Shoei Kisen Kaisha, Ltd. and others. For avoidance of doubt, it is expressly confirmed that the agreements of each Shareholder in the preceding provisions of this Section 8.2 shall not, and shall not be construed to, require any Shareholder, without its prior consent in accordance with this Agreement (which for this purpose includes an approved budget), to make any further commitment of capital or to incur any actual or contingent liability, cost, expenditure or other obligation of any kind for the benefit of the Company or any third parties, including suppliers, customers, and LNG vessel charter and other contractual counterparties. In the event that either Party sells its entire interest in the Company the foregoing provisions of this Section 8.2(b) shall terminate.

(c) Cheniere (on behalf of Cheniere LNG, Inc.), the Company and Mercuria agree that the provisions in Section 8.2(a) above supersede and replace that certain Option Agreement dated December 23, 2003 between Cheniere LNG, Inc. and the Company, which is hereby terminated, as of the Effective Date.

Section 8.3 Governing Law

This Agreement and the obligations of the Shareholder hereunder shall be construed and enforced in accordance with the laws of Switzerland, including the Act, excluding any conflicts of law rule or principle which might refer such construction to the laws of another jurisdiction.

Section 8.4 Entirety; Amendments

This Agreement constitutes the entire agreement of the Shareholders regarding the subject matter hereof and supersedes the prior shareholders agreement effective prior to the Effective Date. Except as otherwise provided herein, no amendments to this Agreement shall be binding upon any Shareholder unless set forth in a document duly executed by both Shareholders.

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Section 8.5 Waiver

No consent or waiver, express or implied, by any Shareholder of any breach or default by the other Shareholder in the performance by the other Shareholder of its obligations hereunder shall be deemed or construed to be a consent or waiver to or of any other breach or default in the performance by such other Shareholder of the same or any other obligation hereunder. Failure on the part of any Shareholder to complain of any act or to declare any other Shareholder or the Company in default, irrespective of how long such failure continues, shall not constitute a waiver of rights hereunder.

Section 8.6 Severability

If any provision of this Agreement or the application thereof to any Person or circumstances shall be invalid or unenforceable to any extent, and such invalidity or unenforceability does not destroy the basis of the bargain between the parties, then the remainder of this Agreement and the application of such provisions to other Persons or circumstances shall not be affected thereby and shall be enforced to the greatest extent permitted by law.

Section 8.7 Captions, References

Article and Section headings are for convenience of reference only and shall not affect the construction or interpretation of this Agreement. Whenever the terms “hereof”, “hereby”, “herein”, or words of similar import are used in this Agreement, they shall be construed as referring to this Agreement in its entirety rather than to a particular Section or provision, unless the context specifically indicates to the contrary. Whenever the words “include” and “including” are used herein, they shall be construed to mean “including, without limitation”. Any reference to a particular “Article” or a “Section” shall be construed as referring to the indicated article or Section of this Agreement unless the context indicates to the contrary.

Section 8.8 Jurisdiction

Each of Mercuria and Cheniere hereby irrevocably submits to the exclusive jurisdiction of the Commercial Court of the Canton of Zurich (Handelsgericht des Kantons Zürich), with reserve of appeals to the Swiss Federal Supreme Court (Schweizerisches Bundesgericht), to settle any disputes which may arise out of or in connection with this Agreement or the transactions contemplated hereby.

Section 8.9 Binding Effect; Assignment

All the terms of this Agreement shall be binding on and inure to the benefit of the parties, their successors-in-interest and permitted assigns. Rights under this Agreement may be assigned only in conjunction with a Transfer of Stock permitted under this Agreement.

Section 8.10 No Further Relationship

The Shareholders agree that no Shareholder is the agent of any other Shareholder, and no such Person is authorized to take any action on behalf of the other, except as expressly provided in this Agreement.

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Section 8.11 No Third-Party Beneficiaries

This Agreement is solely for the benefit of the Shareholders, and their respective successors and permitted assigns, and this Agreement shall not otherwise be deemed to confer upon or give to any other third party any remedy, claim, liability, reimbursement, cause of action or other right.

Section 8.12 Counterparts

This Agreement may be executed in two or more counterparts, each of which shall be deemed an original, but all of which constitute but one agreement.

Executed effective as of the Effective Date.

SHAREHOLDERS:	Mercuria Energy Holding B.V.
	By:	/s/ Alain Rappo
	Name:	Alain Rappo
	Title:	Director
	By:	/s/ Anton Klomp
	Name:	Anton Klomp
	Title:	Director
	Address:	Attention: Director
		Koningslaan 112
		3583 GV Utrecht
		Netherlands
		Phone No.: +31 30 608 6131
		Fax No.: +31 30 254 2578
	Cheniere LNG Services, Inc.
	By:	/s/ Charif Souki
	Name:	Charif Souki
	Title:	President
	Address:	Attention: President
		717 Texas Avenue, Suite 3100
		Houston, Texas 77002
		Phone No.: 713-659-1361
		Fax No.: 713- 659- 5459

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With respect to the termination of the original Shareholders Agreement only:

THE COMPANY:	J & S Cheniere S.A.
	By:	/s/ Jarek Astramowicz
	Name:	Jarek Astramowicz
	Title:	Director
	By:	/s/ Marco Dunand
	Name:	Marco Dunand
	Title:	Director
	Address:	Attention: Director
		Route de St-Cergue No. 9
		P.O. Box 1114
		CH-1260 Nyon
		Switzerland
		Phone No.: +41 22 365 1580
		Fax No.: +41 22 365 1576

Attachments:
	Exhibit 2.3 - Initial Budget
	Exhibit 5.2(e) - Delegations of Authorities
	Exhibit 7.3(a)(vi) - 2006 Financial Statement
	Exhibit 7.3(a)(ix) - Company Agreements
	Exhibit 8.2 (a) Form of Sale & Purchase Agreement

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Exhibit 5.2(e)

J&S CHENIERE S.A.

Delegations of Authorities and Initial Commitments

Delegations of Authorities

Last Name	First Name	Title	Budgeted Approvals		Unbudgeted Approvals		Notes
		President	$	2,000,000	$	10,000	(1	)(3)
		Vice President	$	1,000,000	$	5,000
		Operations Manager	$	250,000	$	5,000
		Financial Officer	$	100,000	$	2,500	(2	)

Notes:

(1) Approval for all Time Charter, Bunker and Port Charge Invoices

(2) Approval of all office related expenditures

(3) All commitments in excess of authority require Chairman’s approval and if required, the BoD or Shareholders.

Initial Commitments:

Time Charter Party Agreement with K-Line

Time Charter Party Agreement with Trinity

Bunker Fuel invoices for 2 LNG vessels

Port Charge Invoices for 2 LNG vessels

Services Agreement with Investors Administration Services Limited

Office Costs - London

LNG Shipping Solutions retainer

Exhibit 7.3(a)(ix)

J&S Cheniere S.A.

Schedule of Company Agreements

As of December 31, 2006

1 LNG Carrier Time Charter Party Agreement between J&S Cheniere and Trinity LNG Transport S.A. date August 2004.

2 LNG Carrier Time Charter Party Agreement between J&S Cheniere and “K” Line LNG Transport Co., Ltd. date August 2004.

3 Services Agreement with LNG Shipping Solutions (Keith Bainbridge).

4 Services Agreement Investors Administration Services Limited. (Karim Souki) - terminated prior to the effective date.

5 Master LNG Sale & Purchase Agreements

a) BG LNG Services, Inc

b) Nigeria LNG

c) Oman LNG

d) QatarGas

e) Sonatrach

Note: the above Master Agreements are non-binding until a definitive Confirmation Agreement (specifing: price; volume; delivery dates; load and unloading locations and credit support) has been executed.

Exhibit 8.2(a)

LNG SALE AND PURCHASE AGREEMENT

BETWEEN

J & S CHENIERE S.A.

as Seller

AND

CHENIERE MARKETING, INC.

as Buyer

Dated                     , 2007

TABLE OF CONTENTS

PART ONE PRINCIPAL COMMERCIAL TERMS AND CONDITIONS		II
A.	Term	ii
B.	Change of Control	iii
C.	LNG Quantity	iii
D.	Contract Price	iv
E.	Notices	v
PART TWO GENERAL TERMS AND CONDITIONS		1
ARTICLE 1 DEFINITIONS		1
ARTICLE 2 DELIVERY SCHEDULE		8
2.1	Annual Delivery Program	8
2.2	Three Month Unloading Schedules	11
2.3	Scheduling Representative	12
2.4	Scheduling Priorities	12
ARTICLE 3 TRANSFER OF TITLE AND RISK OF LOSS		13
3.1	Other	13
3.2	Title and Risk of Loss	13
ARTICLE 4 BUYER’S FACILITY		13
4.1	Standard of Operation	13
4.2	Facilities to be Provided	13
4.3	Facilities Not Provided	14
ARTICLE 5 TRANSPORTATION AND UNLOADING		14
5.1	LNG Vessels	14
5.2	LNG Vessel Inspections; Right to Reject LNG Vessel	17
5.3	Advance Notices Regarding LNG Vessel and Cargoes	18
5.4	Notice of Readiness	20
5.5	Berthing Assignment	20
5.6	Unloading Time	21
5.7	Unloading at Buyer’s Facility	23
5.8	LNG Vessel Not Ready for Unloading	23
5.9	Buyer’s Facility Insurance	24
5.10	LNG Vessel Insurance	24
5.11	Port Liability Agreement	25
ARTICLE 6 QUALITY AND MEASUREMENT OF SELLER’S LNG		25
6.1	Quality and Measurement of Seller’s LNG	25
6.2	Off-Specification LNG	26
ARTICLE 7 INVOICES AND PAYMENT		27
7.1	Delivery Invoices and Cargo Documents	27

i

7.2	Other Invoices	28
7.3	Invoice Due Dates	28
7.4	Payment	28
7.5	Disputed Invoices	29
ARTICLE 8 TAXES, DUTIES AND CHARGES		29
8.1	Seller’s Obligations	29
8.2	Buyer’s Obligations	30
8.3	Refund of Taxes	30
ARTICLE 9 LIABILITIES AND FAILURE TO PERFORM		30
9.1	General	30
9.2	Buyer’s Failure to Take Delivery of LNG Quantity	30
9.3	Seller’s Failure to Deliver LNG Quantity	31
9.4	Minimum LNG Quantity	31
9.5	Duty to Mitigate Damages	31
ARTICLE 10 FORCE MAJEURE		32
10.1	Events of Force Majeure	32
10.2	Limitation on Scope of Force Majeure for Customer	32
10.3	Notice	32
10.4	Measures	33
10.5	No Extension of Term	33
10.6	Settlement of Industrial Disturbances	33
10.7	Allocation of Services	33
10.8	Extended Period of Force Majeure	33
ARTICLE 11 ASSIGNMENT		34
11.1	Generally	34
11.2	Permitted Assignments	34
ARTICLE 12 TERMINATION		34
12.1	Early Termination Events	34
12.2	Notice	35
12.3	Consequences of Termination	35
12.4	Consequences of a Share Buyout	35
ARTICLE 13 APPLICABLE LAW		36
ARTICLE 14 DISPUTE RESOLUTION		36
14.1	Dispute Resolution	36
14.2	Expert Determination	39
ARTICLE 15 CONFIDENTIALITY		40
15.1	Confidentiality Obligation	40
15.2	Public Announcements	41
ARTICLE 16 REPRESENTATIONS AND WARRANTIES		41

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ARTICLE 17 NOTICES		42
ARTICLE 18 MISCELLANEOUS		43
18.1	Amendments	43
18.2	Approvals	43
18.3	Successors and Assigns	43
18.4	Waiver	43
18.5	No Third Party Beneficiaries	43
18.6	Rules of Construction	43
18.7	Survival of Rights	43
18.8	Rights and Remedies	44
18.9	Interpretation	44
18.10	Disclaimer of Agency	45
18.11	No Sovereign Immunity	45
18.12	Severance of Invalid Provisions	45
18.13	Compliance with Laws	45
18.14	Expenses	45
18.15	Audit Rights	46
18.16	Scope	46
18.17	Counterpart Execution	46
18.18	No Conflicts / Foreign Corrupt Practices Act/International Boycott	46
Annex I    Measurement and Tests of LNG at Receipt Point
Exhibit A  Form of Port Liability Agreement
Exhibit B  Form of Terminal Use Agreement

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LNG SALE AND PURCHASE AGREEMENT

This LNG SALE AND PURCHASE AGREEMENT (this “Agreement”), dated as of this [    ] day of [                    ], 2007 (the “Effective Date”) is made by and between J&S Cheniere S.A., a company incorporated under the laws of Switzerland with an office at Route de Saint-Cergue 9, P.O. Box 1114, CH1260, Nyon-Switzerland (“Seller”); and Cheniere Marketing, Inc., a Delaware corporation with a place of business at 717 Texas Avenue, Suite 3100, Houston, Texas, U.S.A. 77002 (“Buyer”).

RECITALS

WHEREAS, Seller and Cheniere LNG, Inc., an Affiliate of Buyer, entered into an Option Agreement on December 23, 2003 (the “Option Agreement”), and pursuant to such Option Agreement Seller paid Cheniere LNG, Inc. an option payment of one million U.S. dollars ($1,000,000) for certain options relating to the use of LNG terminal facilities in the Gulf Coast of the United States which Affiliates of Buyer intend to construct;

WHEREAS, Cheniere LNG, Inc. and Cheniere LNG Commercial Services, Inc., a Delaware corporation and a wholly owned subsidiary of Cheniere LNG, Inc., entered into a Contribution, Assignment and Assumption Agreement dated December 14, 2004 whereby Cheniere LNG, Inc. assigned all of its right, title and interest in the Option Agreement to Cheniere LNG Commercial Services, Inc.;

WHEREAS, on December 27, 2004, Cheniere LNG Commercial Services, Inc. changed its name to Cheniere LNG, Inc.;

WHEREAS, Cheniere LNG, Inc. and Buyer are Affiliates and share the same ultimate parent entity, Cheniere Energy, Inc;

WHEREAS, pursuant to the terms of the Option Agreement, Seller was granted the right and option to purchase vaporization capacity on the terms and conditions similar to those Terminal Use Agreements in effect for other users of the facilities;

WHEREAS, Affiliates of the Parties have entered into a certain Shareholder Agreement under the terms of which the Option Agreement was cancelled and it was agreed that the Parties would enter into this Agreement in lieu of a Terminal Use Agreement, which shall be applicable pursuant to the terms set forth herein;

WHEREAS, in August of 2004, Seller entered into long-term time charters for two LNG vessels presently under construction, namely Hull No. 1587 to be owned by K-Line LNG Transport Co., Ltd. and Hull No. S2258 to be owned by Trinity LNG Transport S.A. (the “Chartered LNG Vessels”);

WHEREAS, Buyer has acquired certain rights to unload LNG at Buyer’s Facility;

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WHEREAS, as a means of utilizing the Chartered LNG Vessels, Seller desires to sell, and Buyer desires to purchase, certain firm quantities and certain optional quantities of LNG for importation by Buyer into the United States via Buyer’s Facility; and

WHEREAS, effective as of the Share Buyout as set out in Section 12.4, this Agreement, the entitlement to purchase and sell option quantities of LNG shall terminate and the LNG Quantity shall become a firm commitment pursuant to Section 12.4:

NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged by the Parties hereto and for the mutual covenants contained herein, Buyer and Seller hereby agree as follows:

PART ONE

PRINCIPAL COMMERCIAL TERMS AND CONDITIONS

The Parties hereby incorporate the General Terms and Conditions included as Part Two of this Agreement.

A. Term

1. General. Subject to the provisions of this Agreement, the term of this Agreement (“Term”) shall consist of the Initial Term and, if applicable, any Extension Term.

2. Initial Term. The initial term of this Agreement (“Initial Term”) shall commence on the Effective Date and shall continue in full force and effect until the expiration of five (5) years from the Commercial Start Date. For the purposes hereof, the Commercial Start Date (“Commercial Start Date”) shall be the date on which Buyer’s Facility is first available for the berthing of LNG vessels, the unloading, receiving and storing of LNG, the regasification of LNG and the transportation of Gas to a Downstream Pipeline. The Commercial Start Date shall be a date within the period that commences on October 1, 2007 and ends on June 30, 2008 (such period being the “First Window Period”). The First Window Period shall be narrowed pursuant to the following provisions:

a. No later than six (6) months in advance of the first day of the First Window Period, Buyer shall give Seller written notice of a sixty (60) day period (“Second Window Period”) falling within the First Window Period for the Commercial Start Date; provided that if Buyer fails to give timely notice of same, the Second Window Period shall be the latest possible sixty (60) day period within the First Window Period;

b. No later than sixty (60) days in advance of the first day of the Second Window Period, Buyer shall give Seller written notice of a thirty (30) day period (“Final Window Period”) falling within the Second Window Period for the Commercial Start Date; provided that if Customer fails to give timely notice of same, the Final Window Period shall be the latest possible thirty (30) day period within the Second Window Period; and

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c. No later than thirty (30) days in advance of the first day of the Final Window Period, Buyer shall give Seller written notice of the Commercial Start Date falling within the Final Window Period; provided that if Buyer fails to give timely notice of the same, the Commercial Start Date shall be the latest possible day in the Final Window Period.

The Commercial Start Date shall be postponed to the extent that an event of Force Majeure has the effect of delaying that date to a later date, as more specifically set forth in Section 10.1.

3. Extension Term. Seller shall have the option of up to three (3) additional five (5) year extension terms (each an “Extension Term”). Seller must (a) notify Buyer in writing of its good faith desire to elect the applicable Extension Term at least two (2) years prior to the expiration of the then current Term and (b) no later than one (1) year prior to the expiration of the then current Term send Buyer a binding confirmation (“Binding Confirmation”) that the Term is extended by an Extension Term. Upon Seller’s delivery of a Binding Confirmation to Buyer, along with an option payment to Buyer of one million dollars ($1,000,000) per Extension Term exercised, this Agreement will then be automatically extended for the applicable Extension Term.

B. Capacity Conversion

If: Seller terminates this Agreement in accordance with the provisions of Section 12.1, then Buyer shall cause the owner of the Sabine Pass Terminal, upon Seller’s notice of termination, to enter into a Terminal Use Agreement with Seller substantially in the form of Exhibit B attached hereto. The term of such Terminal Use Agreement shall: (i) commence upon the effective date of such Terminal Use Agreement; and (ii) continue through a date coincident with the last day of the Initial Term or any permitted Extension Term hereunder.

C. LNG Quantity

1. General

Subject to Clause C.2, during each Contract Year in the Term, Seller shall sell and deliver, or cause to be delivered, to Buyer and Buyer shall purchase, receive and pay for at the Contract Price, the LNG Quantity.

2. Seller’s Option

Buyer hereby grants Seller the option to establish on an annual basis the specific quantity Seller will have the right to sell and deliver, or caused to be delivered, to Buyer and Buyer is required to purchase and pay for during each Contract Year (such elected quantity being herein referred to as “LNG Quantity”) pursuant to the following conditions:

a. The LNG Quantity for a Contract Year shall be an amount elected by Seller pursuant to the monthly notices provided under Section 2.2, such amount for a Contract Year to be no less than the Minimum LNG Quantity and no more than seventy eight million four hundred seventy five thousand (78,475,000) MMBTU (or the pro-rata portion of such amount in the event of a partial Contract Year).

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b. In the event of a Share Buyout, as defined in Section 12.4, the term LNG Quantity shall mean seventy eight million four hundred seventy five thousand (78,475,000) MMBTU (or the pro-rata portion of such amount in the event of a partial Contract Year).

c. Each Contract Year, Seller shall have the right to round-up to a Cargo the amount that would otherwise be a partial Cargo (the additional amount so scheduled and purchased being the “Round-Up Quantity Adjustment”).

D. Contract Price

A price (the “Contract Price” or “P”), applicable to LNG unloaded at Buyer’s Facility (as determined in accordance with Section 7.1), shall be calculated by using the following formula as will be in effect in respect of the relevant month:

P = Henry Hub Price x Cargo x         %

For purposes of this Agreement, Henry Hub Price shall be calculated as follows:

(a) For each MMBTU of LNG unloaded at Buyer’s Facility, the Henry Hub Price shall be in US Dollars per MMBTU equal to the average of the Midpoint prices, in US Dollars per MMBTU published by Gas Daily in its Daily Price Survey for the posting for Louisiana-Onshore South, Henry Hub, for each of the five (5) consecutive following Gas Days commencing on the Initial Gas Day as if each of such five (5) Gas Days had been a flow date (for each Gas Day, the “Floating Index”). For purposes hereof, the “Initial Gas Day” shall mean the first Gas Day that commences after the expiration of the twenty four (24) hour period immediately following the Completion of Unloading.

(b) If a Market Disruption Event has occurred with respect the Floating Index for any of the five (5) Gas Days used in calculating the Contract Price, then the Parties shall negotiate in good faith to agree on a replacement component for the Floating Index for the affected Gas Day, and if the Parties have not so agreed on or before the second Business Day following the affected Gas Day then the replacement component for the Floating Index for the affected Gas Day(s) shall be determined within the next two (2) following Business Days with each Party obtaining, in good faith and from non-affiliated market participants in the relevant market, two quotes for prices of Gas for the affected Gas Day of a similar quality and quantity in the geographical location closest in proximity to Buyer’s Facility and averaging

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the four (4) quotes. If either Party fails to provide two (2) quotes, then the average of the other Party’s two (2) quotes shall determine the replacement component for the Floating Price. “Market Disruption Event” means, with respect to the specified index, any of the following events: (a) the failure of the index publisher to announce or publish information necessary for determining the Floating Index; (b) the temporary or permanent discontinuance or unavailability of the index; or (c) the agreement by both Parties that a material change in the formula for or the method of determining the Floating Index has occurred. For the purposes of the calculation of a replacement component for the Floating Index, all numbers shall be rounded to three (3) decimal places. If the fourth decimal number is five (5) or greater, then the third decimal number shall be increased by one, and if the fourth decimal number is less than five (5), then the third decimal number shall remain unchanged. The replacement component will be used to calculate the Contract Price for the Gas Days for which it was determined to apply.

E. Performance by Buyer

Buyer shall have the right to cause any operational duties of Buyer hereunder to be performed by an Affiliate of Buyer. For the avoidance of doubt, it is the intent of the Parties that this provision shall be limited to routine operational duties of Buyer and that in no event shall Buyer have the right to assign payment or other financial obligations under this Agreement except as specifically set forth in Section 11.1. Furthermore, wherever Buyer is obligated pursuant to this Agreement to cause the Buyer’s Facility, or the owner of Buyer’s Facility (including the Sabine Pass Terminal), as applicable, to perform or refrain from performing a certain action, such obligation of the Buyer shall be qualified in its entirety by Buyer’s contractual rights pursuant to Buyer, to the extent of its rights under the terminal use agreement with the Affiliate which owns Buyer’s Facility. Notwithstanding any other provision of this Agreement to the contrary, in all of the cases described in the immediately preceding sentence, Buyer , shall use commercially reasonable efforts to enforce its rights under the applicable terminal use agreement in order to cause the Buyer’s Facility, or the owner of Buyer’s Facility (including the Sabine Pass Terminal), as applicable, to perform or refrain from performing such action in accordance with the terms of this Agreement such Affiliate to perform the duties or obligations under this Agreement required to be performed by Buyer’s Facility.

F. Notices

Pursuant to Article 17, the Parties have designated the following addresses for purposes of notices:

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J&S Cheniere S.A. Route de Saint-Cergue 9 P.O. Box 1114, CH1260 Nyon Switzerland Attention:                                  Fax:                                               Telephone:                                  Cheniere Marketing, Inc. 717 Texas Avenue, Suite 3100 Houston, Texas 77002 Attention: President Fax: (713) 659-5459 Telephone: (713) 659-1361

IN WITNESS WHEREOF, each of the Parties has caused this Agreement to be duly executed and signed by its duly authorized officer as of the Effective Date.

J&S Cheniere S.A.
By:
Name:
Title:
Cheniere Marketing, Inc.
By:
Name:	Mark Stubbe
Title:	Senior Vice President

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PART TWO

GENERAL TERMS AND CONDITIONS

ARTICLE 1

DEFINITIONS

In addition to any terms or expressions defined elsewhere in this Agreement, the terms or expressions set forth below shall have the following meanings in this Agreement:

1.1 “AAA” shall have the meaning set forth in Section 14.1(b).

1.2 “Adverse Weather Conditions” means weather and sea conditions actually experienced at or near Buyer’s Facility that are sufficiently severe either: (a) to prevent an LNG Vessel from proceeding to berth, or unloading or departing from berth, in accordance with one or more of the following: (i) regulations published by a Governmental Authority; (ii) an Approval; or (iii) an order of a Pilot; or (b) to cause a determination by the master of an LNG Vessel that it is unsafe for such vessel to berth, unload or depart from berth.

1.3 “Affiliate” means a Person (other than a Party) that directly or indirectly controls, is controlled by, or is under common control with, a Party to this Agreement, and for such purposes the terms “control”, “controlled by” and other derivatives thereof shall mean the direct or indirect ownership of fifty percent (50%) or more of the voting rights in a Person.

1.4 “Agreement” means this agreement (including Part One and Part Two hereof), together with the Annexes and Exhibits attached hereto, which are hereby incorporated into and made a part hereof, as the same may be hereafter amended.

1.5 “Allotted Unloading Time” shall have the meaning set forth in Section 5.6.

1.6 “Annual Delivery Program” shall have the meaning set forth in Section 2.1(g).

1.7 “Approvals” means all consents, authorizations, licenses, waivers, permits, approvals and other similar documents from or by a Governmental Authority.

1.8 “Available Unloading Date” means at any time an Unloading Date at Buyer’s Facility that is not a Scheduled Unloading Date for Seller or any other Terminal User at that berth.

1.9 “Bankrupt” means a Person that: (i) is dissolved, other than pursuant to a consolidation, amalgamation or merger; (ii) becomes insolvent or is unable to pay its debts or fails or admits in writing its inability generally to pay its debts as they become due; (iii) makes a general assignment, arrangement or composition with or for the benefit of its creditors; (iv) institutes or has instituted against it a proceeding seeking a judgment of insolvency or bankruptcy or any other relief under any bankruptcy or insolvency law or other similar law affecting creditors’ rights, or a petition is presented for its winding-up or liquidation; (v) has a resolution passed for its winding-up, official management or liquidation, other

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than pursuant to a consolidation, amalgamation or merger; (vi) seeks or becomes subject to the appointment of an administrator, provisional liquidator, conservator, receiver, trustee, custodian or other similar official for all or substantially all of its assets; (vii) has a secured party take possession of all or substantially all of its assets, or has a distress, execution, attachment, sequestration or other legal process levied, enforced or sued on or against all or substantially all of its assets; (viii) causes or is subject to an event with respect to it which, under applicable law has an analogous effect to any of the events specified in clauses (i) through (vii) above, inclusive; or (ix) takes any action in furtherance of, or indicating its consent to, approve or acquiescence in any of the foregoing acts.

1.10 “Base Rate” means: the lesser of (i) the applicable LIBOR rate of interest, as adjusted from time to time, plus one percent (1%), and (ii) the maximum rate of interest permitted by applicable law. “LIBOR”, as of the date of determination, means the London Interbank Offered Rate for one-month U.S. dollar deposits appearing on Page 3750 of the Telerate screen (or any successor page) at approximately 11:00 a.m. (London time). In the event that such rate does not appear on Page 3750 of the Telerate screen (or otherwise on such screen), LIBOR shall be determined by reference to such other comparable publicly available service for displaying eurodollar rates. LIBOR shall be established on the first day on which a determination of the Base Rate is to be made under this Agreement and shall be adjusted daily based on the LIBOR quotes made available through the foregoing sources. If LIBOR quotes are not generally available, “Base Rate” shall mean, as of the date of any determination, the weighted average of the rate on overnight federal funds transactions with members of the Federal Reserve System arranged by federal funds brokers as published by the Federal Reserve Bank of New York.

1.11 “Binding Confirmation” shall have the meaning set forth in Clause A.3.

1.12 “British Thermal Unit” or “BTU” means the amount of heat required to raise the temperature of one (1) avoirdupois pound of pure water from fifty-nine (59) degrees Fahrenheit to sixty (60) degrees Fahrenheit at an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch.

1.13 “Business Day” means any day that is not a Saturday, Sunday or legal holiday in the State of Texas, or a day on which banking institutions chartered by the State of Texas, or the United States of America, are legally required or authorized to close.

1.14 “Buyer” means the Party identified as Buyer in the preamble to this Agreement and its permitted successors and assigns.

1.15 “Buyer’s Facility” means either the Sabine Pass Terminal currently under development in western Cameron Parish, Louisiana by Sabine Pass LNG L.P., an Affiliate of Buyer, with whom Buyer has a terminal use agreement in place, or Sabine Pass LNG, L.P. which owns the Sabine Pass Terminal, as the context may require.

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1.16 “Buyer’s Website” means the website of Buyer’s Facility (or, in the case that the website of Buyer’s Facility is unavailable, an alternative electronic means of transmitting written communication with respect to Buyer’s Facility).

1.17 “Cargo” means the quantity of LNG expressed in MMBTU to be transported on an LNG Vessel and purchased and sold pursuant to the terms of this Agreement.

1.18 “Central Time” means U.S. Central Time Zone, as adjusted for Daylight Saving Time and Standard Time.

1.19 “Change in Control” means, with respect to Cheniere Energy: (i) the date on which the incumbent directors cease to constitute a majority of the board of directors of Cheniere Energy; (ii) the date on which any Person acquires more than forty percent (40%) of the outstanding voting common stock of Cheniere Energy, other than with the consent of the board of directors of Cheniere Energy; or (iii) the date on which Cheniere Energy is merged or consolidated with another entity and, as a result of such merger or consolidation, fifty percent (50%) or less of the outstanding voting securities of the surviving or resulting entity is owned directly or indirectly in the aggregate by the holders of the outstanding voting securities of Cheniere Energy immediately prior to such merger or consolidation. For purposes of this Agreement, incumbent directors means Persons constituting the board of directors of Cheniere Energy on the Effective Date and any Person becoming a director of Cheniere Energy after the Effective Date whose election or nomination is (or was) approved in advance by a vote of at least a majority of the then incumbent directors or whose nomination for election is (or was) approved in advance by a nominating committee composed of the then incumbent directors.

1.20 “Chartered LNG Vessels” shall have the meaning set forth in the Recitals.

1.21 “Commercial Start Date” shall have the meaning set forth in Clause A.2.

1.22 “Completion of Unloading” means, in respect of a Cargo, the disconnection of the flange coupling of the discharge manifold of an LNG Vessel from the flange coupling on the unloading line at Buyer’s Facility following unloading of the LNG Vessel and completion of final gauging.

1.23 “Consultation Notice” shall have the meaning set forth in Section 2.1(h).

1.24 “Control” means the direct or indirect ownership of fifty percent (50%) or more of the voting rights in a Person.

1.25 “Contract Price” shall have the meaning set forth in Clause D.

1.26 “Contract Year” means each annual period starting on January 1 and ending on December 31 during the Term of this Agreement; provided, however, that: (a) the first Contract Year shall commence on the Commercial Start Date and end on the following December 31; and (b) the last Contract Year shall commence on January 1 immediately preceding the last day of the Term and end on the last day of the Term as set forth in Clause A.

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1.27 “Cubic Foot” means a volume equal to the volume of a cube each edge of which is one (1) foot in length.

1.28 “Cubic Meter” means a volume equal to the volume of a cube each edge of which is one (1) meter in length.

1.29 “Deemed Contract Price” shall have the meaning set forth in Section 9.4

1.30 “Dispute” means any dispute, controversy or claim (of any and every kind or type, whether based on contract, tort, statute, regulation, or otherwise) arising out of, relating to, or connected with this Agreement, including any dispute as to the construction, validity, interpretation, termination, enforceability or breach of this Agreement, as well as any dispute over the applicability of arbitration or jurisdiction.

1.31 “Downstream Pipeline” means all Gas pipelines with a connection at the delivery point which transport Gas from Buyer’s Facility. For purposes hereof, delivery point means the point of interconnection between the tailgate of the Sabine Pass Terminal and a downstream pipeline.

1.32 “Effective Date” means the date set forth in the preamble of this Agreement.

1.33 “Estimated Time of Arrival” or its abbreviation “ETA” shall have the meaning set forth in Section 5.3(c)(i).

1.34 “Expected Receipt Quantity” means, with respect to a given Cargo, Seller’s reasonable estimate of the quantity of LNG (in MMBTU) expected to be unloaded at the Receipt Point, as set forth in the notice delivered pursuant to Sections 2.1(c)(ii) and 2.2(a), as such notice may be subsequently amended pursuant to Section 5.3(a).

1.35 “Extension Term” shall have the meaning set forth in Clause A.3.

1.36 “Final Window Period” shall have the meaning set forth in Clause A.2.

1.37 “Firm LNG Quantity” shall have the meaning set forth in Section 2.2(a).

1.38 “First Window Period” shall have the meaning set forth in Clause A.2.

1.39 “Force Majeure” shall have the meaning set forth in Section 10.1.

1.40 “Gas Day” means the twenty-four hour period beginning one day at 9 a.m. Central Time and ending the following day at 9 a.m. Central Time.

1.41 “Governmental Authority” means, in respect of any country, any national, regional, state, or local government, any subdivision, agency, commission or authority thereof (including any maritime authorities, port authority or any quasi-governmental agency) having jurisdiction over a Party, Buyer’s Facility, Seller’s Facilities, an LNG Vessel, a Transporter, or a Downstream Pipeline, as the case may be, and acting within its legal authority.

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1.42 “GPA” shall have the meaning set forth in Annex I.

1.43 “Gross Heating Value” means the quantity of heat, expressed in BTUs, produced by the complete combustion in air of one (1) Cubic Foot of anhydrous gas, at a temperature of sixty (60) degrees Fahrenheit and an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch, with the air at the same temperature and pressure as the gas, after cooling the products of the combustion to the initial temperature of the gas and air, and after condensation of the water formed by combustion.

1.44 “Henry Hub Price” shall have the meaning set forth in Clause D.

1.45 “Initial Term” shall have the meaning set forth in Clause A.2.

1.46 “International LNG Terminal Standards” means, to the extent not inconsistent with the express requirements of this Agreement, the international standards and practices applicable to the design, construction, equipment, operation or maintenance of LNG receiving and regasification terminals, established by the following (such standards to apply in the following order of priority): (a) a Governmental Authority having jurisdiction over Buyer’s Facility; (b) the Society of International Gas Tanker and Terminal Operators (“SIGTTO”) to the extent adopted by Buyer’s Facility; and (c) any other internationally recognized non-governmental agency or organization with whose standards and practices it is customary for a Reasonable and Prudent Person operating LNG receiving and regasification terminals to comply.

1.47 “International LNG Vessel Standards” means, to the extent not inconsistent with the expressed requirements of this Agreement, the international standards and practices applicable to the ownership, design, equipment, operation, manning and maintenance of LNG vessels established by the following (such standards to apply in the following order of priority): (a) a Governmental Authority; (b) the International Maritime Organization; (c) SIGTTO; and (d) any other internationally recognized non-governmental agency or organization with whose standards and practices it is customary for a Reasonable and Prudent Person operating LNG vessels to comply.

1.48 “Liabilities” means all liabilities, costs, claims, disputes, demands, arbitrations, suits, legal or administrative proceedings, judgments, damages, losses and expenses (including reasonable attorneys’ fees and other reasonable costs of arbitration, litigation or defense), and any and all fines, penalties and assessments of, or responsibilities to, Governmental Authorities.

1.49 “Liquefied Natural Gas” or “LNG” means processed Natural Gas in a liquid state, at or below its boiling point and at a pressure of approximately one (1) atmosphere.

1.50 “LNG Quantity” shall have the meaning set forth in Clause C.2.

1.51 “LNG Vessel” means an ocean-going vessel suitable for transporting LNG that Seller uses for transportation of LNG to Buyer’s Facility.

1.52 “Loading Port” means the port at which a Cargo is loaded on board an LNG Vessel.

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1.53 “Measurement Dispute” shall have the meaning set forth in Section 14.2(a).

1.54 “Minimum LNG Quantity” means one (1) standard Cargo per Contract Year. For purposes hereof, one (1) Cargo shall be equivalent to no less than 3,200,000 MMBTU.

1.55 “MMBTU” means one million (1,000,000) BTU.

1.56 “Natural Gas” or “Gas” means any hydrocarbon or mixture of hydrocarbons consisting predominantly of methane which is in a gaseous state.

1.57 “Notice of Readiness” or “NOR” shall have the meaning set forth in Section 5.4.

1.58 “Off-Spec LNG” shall have the meaning set forth in Section 6.2(a).

1.59 “Option Agreement” shall have the meaning set forth in the Recitals.

1.60 “Party” and “Parties” means Buyer and Seller, and their respective successors and permitted assigns.

1.61 “Person” means any individual, sole proprietorship, corporation, trust, company, voluntary association, partnership, joint venture, limited liability company, unincorporated organization, institution, Governmental Authority or any other legal entity.

1.62 “Pilot” means any Person engaged by Transporter to come on board an LNG Vessel to assist the master in pilotage, berthing and unberthing of such LNG Vessel.

1.63 “Pilot Boarding Station” shall have the meaning set forth in Section 5.4(a).

1.64 “Port Charges” means, except as hereafter provided, all charges of whatsoever nature (including rates, tolls, and dues of every description) incurred in respect of an LNG Vessel entering or leaving Buyer’s Facility, including charges imposed by fire boats, tugs and escort vessels, the U.S. Coast Guard, a Pilot, and any other Person assisting an LNG Vessel to enter or leave Buyer’s Facility. Port Charges shall not include: (i) costs associated with the clearing of customs at the Receipt Point, including all duties, taxes and other charges payable upon importation of a Cargo; (ii) charges and fees that are incurred on or after the Receipt Point; or (iii) charges or fees that relate to the use of Buyer’s Facility after the Receipt Point.

1.65 “Port Liability Agreement” shall mean the Port Liability Agreement substantially in the form of Exhibit A.

1.66 “Proposed Unloading Date” shall have the meaning set forth in Section 2.1(c)(i).

1.67 “psig” means pounds per square inch gauge.

1.68 “Reasonable and Prudent Person” means a Person seeking in good faith to perform its contractual obligations, and in so doing, and in the general conduct of its undertaking,

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exercising that degree of skill, diligence, prudence and foresight which would reasonably and ordinarily be expected from a skilled and experienced operator engaged in the same type of undertaking under the same or similar circumstances and conditions.

1.69 “Receipt Point” means the point at which the flange coupling of Buyer’s Facility receiving line joins the flange coupling of the LNG unloading manifold on board an LNG Vessel.

1.70 “Round-Up Quantity Adjustment” shall have the meaning set forth in Clause C.2c.

1.71 “Rules” shall have the meaning set forth in Section 14.1(b).

1.72 “Sabine Pass Terminal” means the LNG terminal facility, along the Sabine Neches Waterway under construction by Sabine Pass LNG L.P. in western Cameron Parish, Louisiana.

1.73 “Scheduled Unloading Date” means, for any applicable Contract Year, an Unloading Date that is allocated either to Seller or any Terminal User pursuant to Section 2.1.

1.74 “Scheduling Representative” means the individual appointed by Seller in accordance with Section 2.3.

1.75 “Second Window Period” shall have the meaning set forth in Clause A.2.

1.76 “Seller” means the Party identified as Seller in the preamble to this Agreement and its permitted successors and assigns.

1.77 “Seller’s Facilities” means the Natural Gas production facilities, pipelines and utilities, Natural Gas treatment, liquefaction and related facilities (including gas gathering pipelines and gas pipelines connecting Natural Gas production facilities to the liquefaction and related facilities), LNG storage facilities and berthing and loading port facilities where Seller will load LNG to make deliveries of LNG in accordance with this Agreement, whether or not owned and/or controlled by Seller.

1.78 “Seller’s Preliminary Receipt Schedule” shall have the meaning set forth in Section 2.1(g).

1.79 “Seller Unloading Date Change Request” shall have the meaning set forth in Section 2.2(c).

1.80 “Standard Cubic Foot” or “SCF” means the quantity of Natural Gas, free of water vapor, occupying a volume of one (1) Cubic Foot at a temperature of sixty (60) degrees Fahrenheit and at an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch.

1.81 “Taxes” means all customs, taxes, royalties, excises, fees, duties, levies, sales and use taxes, ad valorem taxes, property taxes and value added taxes, charges and all other assessments, including payments in lieu of taxes, which may now or hereafter be enacted,

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levied or imposed, directly or indirectly, by a Governmental Authority, except Port Charges and taxes based on income, revenues, gross receipts or net worth and all state and local franchise, license, occupation and similar taxes required for the maintenance of corporate existence or to maintain good standing that are assessed against a Party.

1.82 “Term” shall have the meaning set forth in Clause A.1.

1.83 “Terminal User” means any Person with a contractual right to receive LNG terminalling services from Buyer’s Facility. For avoidance of doubt, Buyer may be a Terminal User with respect to any quantity other than the LNG Quantity.

1.84 “Terminal Use Agreement” means the Terminal Use Agreement in the form set forth in Exhibit B.

1.85 “Three Month Unloading Schedule” shall have the meaning set forth in Section 2.2(b).

1.86 “Transporter” means any Person who owns or operates an LNG Vessel.

1.87 “Tribunal” shall have the meaning set forth in Section 14.1(c).

1.88 “Unloading Date” means a twenty-four (24) hour window starting at 6:00 a.m., Central Time on a specified day and ending twenty-four (24) consecutive hours thereafter during which Buyer would make available berthing and LNG unloading services at Buyer’s Facility to either Seller or one of the Terminal Users.

1.89 “Unloading Date Change Request” shall have the meaning set forth in Section 2.2(c).

1.90 “Unloading Services Unavailability” shall have the meaning set forth in Section2.2(d).

ARTICLE 2

DELIVERY SCHEDULE

2.1 Annual Delivery Program

Procedures for the receipt of LNG at the Receipt Point will be in accordance with the following, as well as any additional procedures generally applicable to Terminal Users at Buyer’s Facility:

(a) Seller’s Initial Notice of LNG Quantity. Not later than one hundred and twenty (120) days prior to the beginning of each Contract Year, Seller shall provide Buyer its initial non-binding good faith estimate of the LNG Quantity for the following Contract Year.

(b) Buyer Deliverables. Not later than one hundred and five (105) days prior to the beginning of each Contract Year, Buyer shall provide to the Scheduling Representative: (i) a non-binding written assessment of the dates of any planned maintenance to or modifications of Buyer’s Facility for such Contract Year and the expected impact of such activities on the availability of services; and (ii) a

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preliminary programming schedule nominated by Terminal Users of Buyer’s Facility. Buyer shall cause Buyer’s Facility to use reasonable endeavors, while acting as a Reasonable and Prudent Person, to limit the number of days of any planned maintenance to or modifications of Buyer’s Facility, so that the number of days for any planned maintenance to or modifications of a Buyer’s Facility shall not exceed three (3) consecutive or ten (10) cumulative days in any Contract Year.

(c) Notice from Scheduling Representative. Not later than ninety five (95) days prior to the beginning of each Contract Year, the Scheduling Representative shall provide Buyer with the following:

(i) a programming schedule for the unloading of Seller’s LNG Quantity over the course of the next Contract Year, which schedule shall specify, for each Cargo to be delivered to the Receipt Point, the proposed unloading date (the “Proposed Unloading Date”) of the applicable LNG Vessel and which schedule must result in a delivery pattern whereby: (a) deliveries are reasonably ratable over the Contract Year; (b) deliveries take into consideration the planned maintenance and modification dates furnished to Seller by Buyer as set forth in Section 2.1(b); and (c) deliveries shall not be scheduled so as to utilize both unloading berths at Buyer’s Facility simultaneously; and

(ii) for each Proposed Unloading Date proposed pursuant to Section 2.1(c)(i), the name of the LNG Vessel expected to deliver LNG to Buyer’s Facility (if the identity of the LNG Vessel is known to Seller at such time), the Expected Receipt Quantity, and the anticipated Gross Heating Value of the LNG to be delivered.

(d) Notices from Terminal Users. Seller acknowledges that Terminal Users will submit similar notices to Buyer regarding the matters provided for in Section 2.1(c). Seller further acknowledges that: (i) other Terminal Users may have priority over Seller with regard to the allocated annual schedule for the receipt and delivery of LNG at Buyer’s Facility; and (ii) in the event of a conflict between the proposed annual schedule submitted by Seller pursuant to this Section 2.1 for Buyer’s Facility and similar annual schedules submitted by other Terminal Users for Buyer’s Facility, the annual schedules by such other Terminal Users for Buyer’s Facility may have priority.

(e) Seller Preliminary Receipt Schedule. Seller acknowledges that Buyer’s Facility shall take into consideration the notices that it receives from the Scheduling Representative and the Terminal Users. Not later than ninety (90) days prior to the beginning of each Contract Year, Buyer shall issue to Seller via Buyer’s Website a preliminary receipt schedule for such Contract Year (the “Seller Preliminary Receipt Schedule”) showing a “Scheduled Unloading Date” for the LNG Vessel carrying each of Seller’s scheduled Cargoes, which schedule must result in a delivery pattern in which: (i) deliveries are reasonably ratable over the Contract

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Year; (ii) Buyer’s Facility’s planned maintenance and modification dates are reflected; and (iii) deliveries are not scheduled so as to utilize both unloading berths Buyer’s Facility simultaneously. Seller may propose to Buyer to change any such Scheduled Unloading Date, and Buyer agrees to give due consideration to, and use reasonable efforts to cause Buyer’s Facility to accommodate, such change.

(f) Preliminary Receipt Schedules and Mutual Cooperation. Seller acknowledges that Buyer’s Facility will issue to each Terminal User via the Buyer’s Website a preliminary receipt schedule similar to the Seller Preliminary Receipt Schedule described in Section 2.1(e), but customized for each such Terminal User. Seller also acknowledges that conflicts will occur in the preparation of the Seller Preliminary Receipt Schedule and other preliminary receipt schedules because of the joint use of Buyer’s Facility among the Terminal Users. Accordingly, Seller agrees to reasonably cooperate with Buyer to assist Buyer in resolving any such conflict to the extent such cooperation does not result in material additional costs to Seller or unduly adversely impact the services provided to Seller hereunder.

(g) Consultation; Annual Delivery Program. If the Scheduling Representative desires to consult with Buyer regarding the contents of the Seller Preliminary Receipt Schedule, the Scheduling Representative shall, no later than fifteen (15) days from the issuance of the Seller Preliminary Receipt Schedule, request to meet with Buyer by providing notice thereof (a “Consultation Notice”) to Buyer, and Buyer shall, no later than fifteen (15) days after receipt of the Consultation Notice, meet with the Scheduling Representative to discuss the Seller Preliminary Receipt Schedule. If: (i) the Scheduling Representative does not submit a Consultation Notice to Buyer on a timely basis; or (ii) the Scheduling Representative and Buyer meet pursuant to a Consultation Notice and are able during such meeting to agree upon revisions to the Seller Preliminary Receipt Schedule, then such Seller Preliminary Receipt Schedule, as so revised (and as updated from time to time for such Contract Year in accordance with the provisions of this Agreement by Buyer via Buyer’s Website), together with the planned maintenance and modification dates selected by Buyer, shall constitute the “Annual Delivery Program”. If the Scheduling Representative and Buyer meet pursuant to a Consultation Notice and are unable during such meeting to agree upon revisions to the Seller Preliminary Receipt Schedule, then Buyer shall determine, while using its reasonable efforts to accommodate Seller’s views, the Annual Delivery Program. Such Annual Delivery Program shall, to the extent practicable, result in a delivery pattern in which: (i) deliveries are reasonably ratable over the Contract Year; (ii) Buyer’s Facility’s planned maintenance and modification dates are reflected; and (iii) deliveries are not scheduled so as to utilize both unloading berths at Buyer’s Facility simultaneously. Buyer shall issue via the Buyer’s Website) the Annual Delivery Program no later than sixty (60) days prior to the first day of the Contract Year.

(h) Terminal Users Annual Delivery Programs. Seller acknowledges that Buyer’s Facility shall issue to each Terminal User a final receipt schedule similar to the Annual Delivery Program described in Section 2.1(g) but customized for each such Terminal User.

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(i) Adjustment to Schedules. Upon written request by Seller, Buyer shall cause Buyer’s Facility to use reasonable efforts to modify the time periods expressly set forth in Sections 2.1(e) and 2.1(g) to allow Seller to interface these periods with corresponding time periods for scheduling agreed upon by Seller and its LNG suppliers. For purposes of this Section 2.1, Buyer’s Facility shall be deemed to have used reasonable efforts if Buyer’s Facility rejects Seller’s request because it determines, acting as a Reasonable and Prudent Person, that any such modification would infringe on the contractual rights of Terminal Users.

(j) Available Unloading Dates. Throughout the Contract Year, Buyer shall cause Buyer’s Facility to maintain on the Buyer’s Website a current list of Available Unloading Dates.

2.2 Three Month Unloading Schedules

(a) Seller’s Election of Firm LNG Quantity. Not later than the first (1st) day of each month in a Contract Year, Seller shall deliver to Buyer its election of the LNG Quantity to be sold and delivered during the next three months (the “Firm LNG Quantity”), such quantity to be not in excess of that established in the Annual Delivery Program. Such election shall propose Seller’s projected delivery dates for each of the next three (3) months and the Expected Receipt Quantity of each such shipment. In the case of the first month of deliveries hereunder, or any other month that does not immediately follow a prior delivery month, the Parties will mutually agree to an appropriate time period for Seller’s election of the Firm LNG Quantity.

(b) Three Month Unloading Schedules. After the first election made by Seller of the Firm LNG Quantity pursuant to Section 2.2(a), not later than the twentieth (20th) day of each month, Buyer shall deliver to Seller a final three-month forward plan of delivery of the Firm LNG Quantity (“Three Month Unloading Schedule”). The Three Month Unloading Schedule shall reflect to the extent operationally practicable Seller’s proposed Three Month Unloading Schedule and the Firm LNG Quantity as elected in prior Three Month Unloading Schedules.

(c) Seller Changes to the Annual Delivery Program or Three Month Unloading Schedule. At any time following the issuance of the Annual Delivery Program and any applicable Three Month Unloading Schedule, Seller’s Scheduling Representative may submit to Buyer a written request to change a Scheduled Unloading Date to any Available Unloading Date (such request to change, a “Seller Unloading Date Change Request”). Seller understands that: (a) Terminal Users shall also have the right to submit to Buyer’s Facility similar scheduling requests; (b) Buyer shall have no obligation to consult with the Scheduling Representative, Seller, or Terminal Users regarding any Seller Unloading Date Change Request or Terminal User unloading date change request

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(collectively, “Unloading Date Change Requests”); and (c) Seller acknowledges that Buyer’s Facility shall accept any Unloading Date Change Request on a first-come, first-served basis. Upon accepting a Seller Unloading Date Change Request, Buyer shall notify Seller via the Buyer’s Website as soon as practical but not later than 5:00 p.m. Central Time of the day following the date of receipt by Buyer of the applicable Unloading Date Change Request. Notwithstanding anything herein to the contrary, Seller shall use its reasonable efforts to keep to a minimum the number of Seller Unloading Date Change Requests it submits to Buyer.

(d) Other Modifications to the Annual Deliver Program or Three Month Unloading Schedule. If Seller is unable to berth during its Scheduled Unloading Date due to a Force Majeure event (an “Unloading Services Unavailability”), each affected Scheduled Unloading Date allocated to Seller during such period shall be cancelled, to the extent affected; provided, however, that in the event of an Unloading Services Unavailability causing the cancellation of one or more Scheduled Unloading Dates allocated to Seller and/or Terminal Users, Buyer shall make reasonable efforts to cause Buyer’s Facility to change the Three Month Unloading Schedule and Annual Delivery Programs of Terminal Users in order to maximize efficient usage of Buyer’s Facility to assist Seller and Terminal Users to unload quantities of LNG which would otherwise have been unloaded at Buyer’s Facility during such cancelled Scheduled Unloading Dates

(e) Buyer’s Terminal Designation. For each Scheduled Unloading Date allocated to Seller hereunder, Buyer, in its sole discretion shall have the right up to and including the fifth (5th) day prior to such Scheduled Unloading Date to designate in writing to Seller an alternate facility with which Buyer has a terminal use agreement in place other than that to which receipt was preliminarily scheduled in accordance with this Article 2; provided that, Buyer agrees to reimburse Seller for any additional transportation costs arising as a result of such deviation to an alternate facility in the U.S. Gulf Coast. Thereafter, Seller shall be obligated to deliver such Cargo to such alternate Buyer’s facility.

2.3 Scheduling Representative

By no later than six (6) months prior to the Commercial Start Date, Seller shall appoint an individual to act as Scheduling Representative for the purposes of this Article 2; provided, however, that Seller shall have the right to change its appointed Scheduling Representative at any time by notice to Buyer. Unless otherwise stated herein, Seller hereby authorizes the Scheduling Representative to do and perform any and all acts for and on behalf of Seller with regard to scheduling matters provided for in this Article 2.

2.4 Scheduling Priorities

The Parties acknowledge that Buyer’s Facility has entered into an agreement with Total LNG USA, Inc. (“TOTAL”) that grants TOTAL certain scheduling priorities for LNG unloading at Buyer’s Facility. Subject to such rights granted to TOTAL, Buyer confirms that its contractual scheduling rights for LNG unloading at Buyer’s Facility [are not inferior to the contractual rights of other Terminal Users at Buyer’s Facility]

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ARTICLE 3

TRANSFER OF TITLE AND RISK OF LOSS

3.1 Other

Seller warrants that it will have the right to convey and will transfer good and merchantable title to all LNG sold hereunder, and covenants that it will have the right to sell the same. Seller warrants that LNG sold hereunder will be free from liens, encumbrances, adverse claims and proprietary rights at the passing of title and that no circumstances will then exist which could give rise to any such encumbrances, adverse claims or proprietary rights other than those that may be caused by acts or omissions of Buyer.

3.2 Title and Risk of Loss

Title to the LNG sold and purchased under this Agreement will transfer automatically to Buyer at the international transfer receipt point to be located outside of the jurisdictional waters of the United States, without the need for any particular action on the +the part of either Party. Notwithstanding the foregoing, risk of loss to the LNG sold and purchased under this Agreement will transfer automatically to Buyer at the Receipt Point, without the need for any particular action on the part of either Party.

ARTICLE 4

BUYER’S FACILITY

4.1 Standard of Operation

On and after the Commercial Start Date, Buyer shall cause Buyer’s Facility to be provided, maintained and operated in accordance with the following: (a) all Approvals required by Governmental Authorities; (b) International LNG Terminal Standards; and (c) to the extent not inconsistent with International LNG Terminal Standards, such good and prudent practices as are generally followed in the LNG industry by a Reasonable and Prudent Person operating LNG receiving and regasification terminals.

4.2 Facilities to be Provided

Subject to Section 4.1, the terminal use agreement between Buyer and Buyer’s Facility shall include the following:

(a) appropriate systems for communications with LNG Vessels;

(b) unloading berths, which LNG Vessels can safely reach, fully laden, and safely depart, and at which LNG Vessels can lie safely berthed and unload safely afloat;

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(c) lighting sufficient to permit berthing, unberthing and unloading operations by day or by night, to the extent permitted by Governmental Authorities and Pilots (it being acknowledged, however, that Buyer’s Facility shall in no event be obligated to allow nighttime berthing operations at Buyer’s Facility if Buyer’s Facility determines, acting as a Reasonable and Prudent Person, that such operations during nighttime hours could pose safety or operational risks to Buyer’s Facility, an LNG Vessel, or a third party);

(d) unloading facilities capable of receiving LNG at a rate of up to an average of 12,000 Cubic Meters per hour when the pressure at the Receipt Point is at least 5.6 bars (gauge), with three (3) unloading arms each having a reasonable operating envelope to allow for ship movement and manifold strainers of sixty (60) mesh;

(e) a vapor return line system of sufficient capacity to transfer to an LNG Vessel quantities of Gas necessary for the safe unloading of LNG at the required rates, pressures and temperatures;

(f) facilities allowing ingress and egress between Buyer’s Facility and the LNG Vessel by: (i) representatives of Governmental Authorities for purposes of unloading operations; and (ii) an independent surveyor for purposes of conducting tests and measurements of LNG on board the LNG Vessel in accordance with Annex I;

(g) LNG storage facilities with a total gross capacity sufficient for the purposes of this Agreement;

(h) LNG regasification facilities sufficient for the purposes of this Agreement; and

(i) piping, flange and mooring equipment necessary to discharge Cargo.

4.3 Facilities Not Provided

Services and facilities not provided at Buyer’s Facility include the following: (a) facilities and loading lines for liquid or gaseous nitrogen to service an LNG Vessel; (b) facilities for providing bunkers; and (c) facilities for the handling and delivery to the LNG Vessel of ship’s stores, provisions and spare parts.

ARTICLE 5

TRANSPORTATION AND UNLOADING

5.1 LNG Vessels

(a) General. Seller shall be responsible for the transportation of LNG from the Loading Port to the Receipt Point. In this regard, Seller shall cause each LNG Vessel to comply with the requirements of this Article 5 in all respects.

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(b) Approvals and Documentation. Each LNG Vessel shall comply with the regulations of and obtain all Approvals to enable such LNG Vessel to enter, leave and carry out all required operations at Buyer’s Facility. Each LNG Vessel shall at all times have on board valid documentation evidencing all such Approvals. Each LNG Vessel shall comply fully with the International Safety Management Code for the Safe Operation of Ships and Pollution Prevention effective July 1, 1998, and at all times be in possession of a valid safety management certificate.

(c) Tugs, Fireboats and Escort Vessels. Seller shall arrange for, or cause the appropriate Person to arrange for, such number and types of tugs, fireboats and escort vessels as are required by Governmental Authorities to attend the LNG Vessel so as to permit safe and efficient movement of the LNG Vessel within the maritime safety areas located in the approaches to and from Buyer’s Facility.

(d) LNG Vessel Requirements. Each LNG Vessel must satisfy the following requirements:

(i) General. Except as otherwise agreed in writing by Buyer, each LNG Vessel shall:

a. have a displacement of no more than 166,600 tonnes, an overall length of no more than 1,140 feet, a beam of no more than 175 feet, and a draft of no more than 40 feet; and

b. be otherwise fully compatible (including in relation to displacement, length, beam and draft) with Buyer’s Facility. Notwithstanding the foregoing, in the event an LNG Vessel is compatible with Buyer’s Facility, but a Governmental Authority or Pilot prohibits or otherwise hinders the utilization of such LNG Vessel, Seller’s transportation obligations under this Agreement shall not be excused or suspended by reason of Seller’s inability (pursuant to the foregoing) to use such vessel as an LNG Vessel.

Buyer shall nevertheless, make reasonable efforts to accept a nonconforming LNG Vessel if such acceptance would not create a contractual, safety or operational hardship for Buyer’s Facility. Seller will provide Buyer with design specifications for the Chartered LNG Vessels and the Parties shall cooperate to determine that the Chartered LNG Vessels are physically compatible with Buyer’s Facility.

(ii) LNG Vessel Capacity. Except as otherwise agreed in writing by Buyer, each LNG Vessel shall have an LNG cargo containment capacity of no less than eighty seven thousand six hundred (87,600) Cubic Meters.

(iii) Condition of the LNG Vessel. Each LNG Vessel shall be, in accordance with International LNG Vessel Standards: (a) fitted in every way for the safe loading, unloading, handling and carrying of LNG in bulk at atmospheric pressure; and (b) tight, staunch, strong and otherwise

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seaworthy with cargo handling and storage systems (including instrumentation) necessary for the safe loading, unloading, handling, carrying and measuring of LNG in good order and condition. The location of the unloading manifold shall allow a safe margin for movement of the arms within the operating envelope.

(iv) Classification Society. Each LNG Vessel shall at all times be maintained in class with any of the following: American Bureau of Shipping, Lloyd’s Register for Shipping, Bureau Veritas, Germanischer Lloyd, NKK, Det Norske Veritas or any other classification society that is mutually agreeable to the Parties.

(v) Construction. Each LNG Vessel shall have been constructed to all applicable International LNG Vessel Standards (including the International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk).

(vi) Operation and Maintenance. Each LNG Vessel shall comply with, and shall be fully equipped, supplied and maintained to comply with, all applicable International LNG Vessel Standards. Unless approved by Buyer’s Facility in writing, an LNG Vessel shall be prohibited from engaging in any maintenance, repair or in-water surveys while berthed at Buyer’s Facility, other than minor housekeeping repairs that do not materially affect the operation of the LNG Vessel. Each LNG Vessel shall comply fully with the guidelines of any Governmental Authority of the United States, including the National Oceanographic and Atmospheric Administration (NOAA), in relation to actions to avoid strikes in U.S. waters with protected sea turtles and cetaceans (e.g., whales and other marine mammals) and with regard to the reporting of any strike by the LNG Vessel which causes injury to such protected species.

(vii) Crew. The officers and crew of each LNG Vessel shall have the ability, experience, licenses and training commensurate with the performance of their duties in accordance with internationally accepted standards as adopted on first-class LNG vessels and as required by Governmental Authorities and any labor organization having jurisdiction over the LNG Vessel or her crew. Without in any way limiting the foregoing, the master, chief engineer, all cargo engineers and all deck officers shall be fluent in written and oral English and shall maintain all records and provide all reports with respect to the LNG Vessel in English.

(viii) Communications. Each LNG Vessel shall have communication equipment complying with applicable regulations of Governmental Authorities and permitting such LNG Vessel to be in constant communication with Buyer’s Facility and with other vessels in the area (including fireboats, escort vessels and other vessels employed in port operations).

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(ix) Pumping Time. Provided that Buyer’s Facility supplies a suitable vapor return line meeting the requirements of Section 4.2(e), then:

a. an LNG Vessel with an LNG cargo containment capacity less than or equal to one hundred forty thousand (140,000) Cubic Meters shall be capable of unloading LNG in a maximum of fifteen (15) hours; and

b. an LNG Vessel with an LNG cargo containment capacity greater than one hundred forty thousand (140,000) Cubic Meters shall be capable of unloading LNG in the number of hours derived after applying the following formula:

15 + x = maximum LNG unloading time (in hours)

where:

x = y/12,000 Cubic Meters; and

y = the LNG cargo containment capacity of the LNG Vessel in excess of 140,000 Cubic Meters.

Time for connecting, cooling, stripping and disconnecting, and cooling of liquid arms shall not be included in the computation of pumping time.

5.2 LNG Vessel Inspections; Right to Reject LNG Vessel

(a) Inspections. During the Term, on prior reasonable notice to Seller, Buyer’s Facility acting as a Reasonable and Prudent Person may, at its sole risk, send its representatives (including an independent internationally recognized maritime consultant) to inspect during normal working hours any LNG Vessel as Buyer’s Facility may consider necessary to ascertain whether the LNG Vessel complies with the provisions of this Agreement. Buyer’s Facility shall bear the costs and expenses in connection with any inspection conducted hereunder. Any such inspection may include, as far as is practicable having regard to the LNG Vessel’s operational schedule, examination of the LNG Vessel’s hull, cargo and ballast tanks, machinery, boilers, auxiliaries and equipment; examination of the LNG Vessel’s deck and engine scrap/rough and fair copy/official log books; review of records of surveys by the LNG Vessel’s classification society and relevant Governmental Authorities; and review of the LNG Vessel’s operating procedures and performance of surveys, both in port and at sea. Any inspection carried out pursuant to this Section 5.2(a): (i) shall not interfere with, or hinder, any LNG Vessel’s safe and efficient construction or operation; and (ii) shall not entitle Buyer’s Facility or any of its representatives to make any request or recommendation directly to Transporter except through Seller. No inspection (or lack thereof) of an LNG Vessel hereunder shall: (x) modify or amend Seller’s obligations, representations, warranties and covenants under this Agreement or under any agreement or instrument contemplated by this Agreement; or (y) constitute an acceptance or waiver by Buyer or Buyer’s Facility of Seller’s obligations under this Agreement.

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(b) Right to Reject LNG Vessel. Buyer’s Facility shall have the right to reject any LNG Vessel that Seller intends to use to deliver LNG to Buyer’s Facility if such LNG Vessel does not comply materially with the provisions of this Agreement, provided that:

(i) neither the exercise nor the non-exercise of such right shall reduce the responsibility of Seller to Buyer in respect of such LNG Vessel and her operation, nor increase Buyer’s responsibilities to Seller or third parties for the same;

(ii) Seller’s obligations under this Agreement shall not be excused or suspended by reason of Seller’s inability (pursuant to the foregoing) to use a vessel as an LNG Vessel; and.

(iii) Buyer shall use all commercially reasonably efforts to ensure that Buyer’s Facility approval of any LNG Vessel shall not be unreasonably withheld.

Buyer shall use commercially reasonable efforts to notify Seller as promptly as possible of any known objection it or Buyer’s Facility has to Seller’s nominated LNG Vessel subsequent to Seller’s designation of such vessel as a LNG Vessel.

5.3 Advance Notices Regarding LNG Vessel and Cargoes

(a) Change in Expected Receipt Quantity. If, subsequent to issuing the notice required under Section Error! Reference source not found. and Section 2.1(c), Seller anticipates a change, by way of either increase or decrease, of more than five percent (5%) in the Expected Receipt Quantity for a particular Cargo, Seller shall promptly provide notice thereof to Buyer and include in such notice Seller’s new estimate of the Expected Receipt Quantity. Buyer shall use reasonable endeavors to accept any increase in the Expected Receipt Quantity but shall at all times have the right not to accept such new increased quantity if, in its reasonable discretion, such increased quantity would conflict with any Terminal Users unloading schedule or entitlement to services or exceed Seller’s rights at Buyer’s Facility as a result of this Agreement.

(b) LNG Vessel Nomination. As soon as practicable but no later than five (5) days prior to the scheduled loading date for a Cargo (unless the Cargo is a diversion cargo, in which case the notification shall be as soon as practicable after such diversion), Seller shall notify Buyer of the information specified below:

(i) name of LNG Vessel and, in reasonable detail, the dimensions, specifications, operator, and owner of such LNG Vessel;

(ii) name of Loading Port;

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(iii) expected departure date of LNG Vessel from Loading Port;

(iv) estimated arrival date at Buyer’s Facility; and

(v) any changes in the Expected Receipt Quantity since the most recent notice given by Seller pursuant to Section 2.1(c) or Section 5.3(a), as the case may be.

(c) LNG Vessel Movements. With respect to each Cargo of LNG to be delivered hereunder, Seller shall give, or cause the master of the LNG Vessel to give, to Buyer the following notices:

(i) A first notice (“First Notice”), which shall be sent within twelve (12) hours of departure of the LNG Vessel from the Loading Port and which shall set forth the time and date that loading was completed, the volume (expressed in Cubic Meters) of LNG loaded on board the LNG Vessel, the estimated time of arrival of the LNG Vessel at the Pilot Boarding Station (“ETA”), and any operational deficiencies in the LNG Vessel that may affect its performance at Buyer’s Facility or berth;

(ii) A second notice (“Second Notice”), which shall be sent ninety-six (96) hours prior to the ETA set forth in the First Notice, stating the LNG Vessel’s then ETA. If, thereafter, such ETA changes by more than six (6) hours, Seller shall give promptly, or cause the master of the LNG Vessel to give promptly, to Buyer, notice of the corrected ETA;

(iii) A third notice (“Third Notice”), which shall be sent twenty-four (24) hours prior to the ETA set forth in the Second Notice (as corrected), confirming or amending such ETA. If, thereafter, such ETA changes by more than three (3) hours, Seller shall give promptly, or cause the master of the LNG Vessel to give promptly, to Buyer notice of the corrected ETA;

(iv) A fourth notice (“Final Notice”), which shall be sent twelve (12) hours prior to the ETA set forth in the Third Notice (as corrected), confirming or amending such ETA. If, thereafter, such ETA changes by more than one (1) hour, Seller shall give promptly, or cause the master of the LNG Vessel to give promptly, to Buyer notice of the corrected ETA; and

(v) An NOR, which shall be given at the time prescribed in Section 5.4 below.

(d) Characteristics of Cargoes. With the First Notice, Seller shall notify Buyer, or cause Buyer to be notified, for Buyer’s information only, of the following characteristics of the LNG comprising its Cargo as determined at the time of loading:

(i) Gross Heating Value per unit;

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(ii) molecular percentage of hydrocarbon components and nitrogen;

(iii) average temperature; and

(iv) density at loading.

5.4 Notice of Readiness

(a) Issuance. Subject to any applicable restrictions, including any nighttime transit restrictions imposed by Governmental Authorities or Pilots or any other reasonable timing restrictions imposed by Buyer, the master of an LNG Vessel or its agent shall give to Buyer its notice of readiness (“NOR”), to unload (berth or no berth) upon arrival of such LNG Vessel at the specific location off Buyer’s Facility at which Pilots customarily board the LNG Vessel (such location referred to as the “Pilot Boarding Station”).

(b) Effectiveness. An NOR given under Section 5.4(a) shall become effective as follows:

(i) For an LNG Vessel arriving at the Pilot Boarding Station at any time before 6:00 a.m. Central Time on the Scheduled Unloading Date allocated to such LNG Vessel, an NOR shall be deemed effective at 6:00 a.m. Central Time on such Scheduled Unloading Date;

(ii) For an LNG Vessel arriving at the Pilot Boarding Station at any time between the period of 6:00 a.m. Central Time on the Scheduled Unloading Date allocated to such LNG Vessel and 6:00 a.m. Central Time on the day immediately following such Scheduled Unloading Date, an NOR shall become effective at the time of its issuance; or

(iii) For an LNG Vessel arriving at the Pilot Boarding Station at any time after the expiration of the Scheduled Unloading Date, an NOR shall become effective upon Buyer’s notice to the LNG Vessel that it is ready to receive the LNG Vessel at berth.

5.5 Berthing Assignment

(a) General Rule. Buyer’s Facility shall determine the berthing sequence of all LNG vessels at Buyer’s Facility in order to ensure compliance with the Annual Delivery Program and Three Month Unloading Schedules. If an LNG Vessel is not ready to unload for any reason, Buyer’s Facility may refuse to allow it to berth.

(b) Timely Arrival. Buyer’s Facility shall berth an LNG Vessel arriving before or during its Scheduled Unloading Date at the first opportunity that Buyer’s Facility reasonably determines such LNG Vessel will not interfere with the berthing and unloading of any other scheduled LNG vessel with a higher berthing priority. Berthing priority for LNG vessels arriving before or during their respective Scheduled Unloading Dates shall be determined as follows:

(i) The first berthing priority on any day shall be for LNG vessels with a Scheduled Unloading Date on such day. Priority within this group shall be given to the LNG vessel which has first given Buyer’s Facility its NOR; and

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(ii) The second berthing priority on any day shall be for LNG vessels with a Scheduled Unloading Date on a future day. Priority within this group shall be given to the LNG vessel which has first given Buyer’s Facility its NOR.

For the avoidance of doubt, Buyer’s Facility will allow berthing and unloading of LNG vessels from the priority group in Sections 5.5(b)(ii) above only if, in the reasonable judgment of Buyer’s Facility, such berthing and unloading will not cause Buyer’s Facility to lack either berthing space or sufficient storage capacity to allow unloading of an LNG vessel on its Scheduled Unloading Date.

(c) Late Arrival. Buyer’s Facility shall berth an LNG Vessel arriving after its Scheduled Unloading Date at the first opportunity that Buyer’s Facility reasonably determines such LNG Vessel will not cause Buyer’s Facility to lack either berthing space or sufficient storage capacity to allow unloading of an LNG vessel from the priority group in Section 5.5(b)(i).

5.6 Unloading Time

(a) Allotted Unloading Time. The allotted unloading time for each LNG Vessel (“Allotted Unloading Time”) shall be thirty-six (36) hours, subject to extensions for:

(i) reasons attributable to Seller, a Pilot, a Governmental Authority, the LNG Vessel or its master, crew, owner or operator, tugs, line boats, service boats, fire boats or other escort vessels, or attributable to any other party whose performance is required for the transiting and berthing of the LNG Vessel and whose performance is outside the control of Buyer’s Facility;

(ii) Force Majeure;

(iii) unscheduled curtailment or temporary discontinuation of operations at Buyer’s Facility provided that the repairs giving rise to such curtailment or discontinuance are reasonably necessary for the delivery of services to Seller or for reasons of safety;

(iv) occupancy of the berth by an LNG vessel that arrived at berth at Buyer’s Facility no later than 6:00 p.m. Central Time of the scheduled unloading window allocated to such LNG vessel, which shall result in an extension of no more than nine (9) hours;

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(v) additional time to unload an LNG Vessel with an LNG cargo containment capacity greater than one hundred forty thousand (140,000) Cubic Meters, such increase over thirty-six (36) hours to be calculated in the same manner as increases over twenty-four (24) hours under Section 5.1(d)(ix)b;

(vi) failure of an LNG Vessel to send the Final Notice pursuant to Section 5.3(c)(iv) or, failure of an LNG Vessel to give an NOR within six (6) hours of the ETA given to Buyer in the Second Notice pursuant to Section 5.3(c)(ii); and

(vii) night time transit restrictions.

For the avoidance of doubt, Buyer’s Facility shall have the right to delay berthing of the LNG Vessel for any of the reasons set forth in (i) to (vii) above.

(b) Actual Unloading Time. The actual unloading time for each LNG Vessel (“Actual Time”) shall commence when the NOR is effective and shall end when the unloading and return lines of the LNG Vessel are disconnected from Buyer’s Facility’s unloading and return lines.

(c) Demurrage

In the event Actual Unloading Time exceeds Allotted Unloading Time (including any extension in accordance with Section 5.6(a) (“Demurrage Event”), Buyer shall pay to Seller as liquidated damages demurrage in United States dollars (which shall be prorated for a portion of a day) determined in accordance with the rate set out in the following table:

LNG Vessel Cargo Capacity	Demurrage Rate in $/day
Less than 120,000 Cubic Meters	$	45,000
120,000 Cubic Meters or greater up to, but not including, 160,000 Cubic Meters	$	55,000
160,000 Cubic Meters or greater up to, but not including, 200,000 Cubic Meters	$	65,000
200,000 Cubic Meters or greater	$	83,000

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If a Demurrage Event occurs, Seller shall invoice Buyer pursuant to Section 7.2 for such demurrage within thirty (30) days.

(d) Excess Boil-Off. If an LNG Vessel is delayed in berthing at Buyer’s Facility and/or commencement of unloading due to an event occurring at Buyer’s Facility and for a reason that would not result in an extension of Allotted Unloading Time under Section 5.6(a), and if, as a result thereof, the commencement of unloading is delayed beyond twenty-four (24) hours after the NOR is effective; then, for each full hour by which commencement of unloading is delayed beyond such twenty-four (24) hour period, Buyer shall pay Seller as liquidated damages an amount, on account of excess boil-off, equal to the Henry Hub Price multiplied by the quantity in MMBTUs equal to 0.0052% of the Cargo. Seller shall invoice Buyer for such excess boil-off pursuant to Section 7.2. This provision shall not apply if the LNG Vessel has onboard re-liquefaction capability for boil-off.

(e) Force Majeure Unloading Delays. If an LNG Vessel that has given NOR is preventing from completion of unloading of a Cargo at Buyer’s Facility due to the occurrence of a Force Majeure (other than Adverse Weather Conditions) for a period exceeding two (2) days and such Cargo cannot be unloaded at another facility at which Buyer has a terminal use agreement in place on a timely basis, then Buyer shall reimburse Seller for the actual, reasonable and documented incremental costs incurred by Seller in transporting and unloading such Cargo at an alternative LNG receiving facility in the U.S. Gulf Coast.

5.7 Unloading at Buyer’s Facility

(a) Efficiency. Buyer shall cooperate with Transporters (or their agents) and with the master of each LNG Vessel to facilitate the continuous and efficient delivery of LNG hereunder.

(b) Vapor Return Line. During unloading of each Cargo of LNG, Buyer shall cause Buyer’s Facility to return to the LNG Vessel Gas in such quantities as are necessary for the safe unloading of the LNG at such rates, pressures and temperatures as may be required by the design of the LNG Vessel, and such returned Gas shall not be deemed to be volume unloaded for Seller’s account.

5.8 LNG Vessel Not Ready for Unloading

If any LNG Vessel, previously believed to be ready for unloading, is determined to be not ready after being berthed, Buyer’s Facility may direct the LNG Vessel’s master to vacate the berth and proceed to anchorage, whether or not other LNG vessels are awaiting the berth, unless it appears reasonably certain to Buyer’s Facility that such LNG Vessel can be made ready without disrupting the overall unloading schedule of Buyer’s Facility or operations of Buyer’s Facility. When an unready LNG Vessel at anchorage becomes ready for unloading, its master shall notify Buyer. Upon the re-berthing of any LNG Vessel vacated pursuant to this Section 5.8, Seller shall be responsible for any actual

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costs incurred by Buyer acting as a Reasonable and Prudent Person as a result of such LNG Vessel not being ready for unloading. If an LNG Vessel is ready for unloading and Buyer or Buyer’s Facility nonetheless directs the LNG Vessel to vacate the berth, Buyer shall indemnify and hold Seller harmless for all Liabilities resulting from causing the LNG Vessel to leave the berth and delay discharging the Cargo.

5.9 Buyer’s Facility Insurance

Buyer’s Facility under its terminal use agreement with Buyer shall be responsible for obtaining and maintaining insurance for Buyer’s Facility to the extent required by applicable law; and additional insurance, as is reasonably necessary and available on reasonable commercial terms, against such other risks and at such levels as a Reasonable and Prudent Person operating a shared use LNG receiving and regasification terminal would obtain. Under such agreement, Buyer’s Facility has agreed to obtain such insurance from a reputable insurer (or insurers) reasonably believed to have adequate financial reserves. Any insurance policy required pursuant to this Section 5.9 shall contain a standard waiver of subrogation endorsement. In the event of a casualty that destroys or materially impairs Buyer’s Facility, Buyer shall use all commercially reasonable efforts to cause Buyer’s Facility, upon consent of Lenders, to utilize such insurance proceeds to cause the facility to be rebuilt or repaired as quickly as commercially practicable. In any event Buyer’s Facility has covenanted under its agreement with Buyer that Buyer’s Facility shall be required to obtain the following insurance coverages:

(a) Commercial General Liability Insurance / Marine Terminal Operator’s Liability Insurance;

(b) Workers’ Compensation / Employer’s Liability Insurance;

(c) All-Risk Property Insurance; and

(d) Wharfingers Liability Insurance.

5.10 LNG Vessel Insurance

Seller shall ensure that insurances are procured and maintained for each LNG Vessel in accordance with the following provisions. In all cases, such insurance shall establish insurance coverages consistent with insurances to the standards which a ship owner operating reputable LNG vessels, as a Reasonable and Prudent Person, should observe in insuring LNG vessels of similar type, size, age and trade as such LNG Vessel. In this regard:

(a) Hull and Machinery Insurance shall be placed and maintained with reputable marine underwriters; and

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(b) Protection & Indemnity Insurance (“P&I Insurance”) shall be placed and maintained as an unlimited entry, if such entry is available, with, and subject to, and on the basis of, the rules of any of the reputable international P&I Insurance associations experienced in providing P&I Insurance for LNG vessels.

5.11 Port Liability Agreement

Notwithstanding any other provision of this Agreement and any rights that a Transporter may have under applicable law, Buyer’s Facility and Seller agree to a Port Liability Agreement set forth in Exhibit A in relation to Liabilities for incidents involving an LNG Vessel occurring at Buyer’s Facility. Seller shall cause Transporter to execute the Port Liability Agreement in the form set forth on Exhibit A prior to Transporter’s LNG Vessel’s arrival at Buyer’s Facility. In the event a Transporter fails to execute such Port Liability Agreement, Seller shall indemnify and hold Buyer’s Facility harmless from any Liabilities incurred by Buyer’s Facility arising from such failure.

ARTICLE 6

QUALITY AND MEASUREMENT OF SELLER’S LNG

6.1 Quality and Measurement of Seller’s LNG

LNG sold hereunder shall be measured and tested in accordance with Annex I. Seller shall ensure that all LNG sold hereunder shall conform to the following specifications:

(a) Gross Heating Value. LNG when unloaded at Buyer’s Facility shall have, in a gaseous state, a Gross Heating Value of not less than 950 BTU per Standard Cubic Foot and not more than 1165 BTU per Standard Cubic Foot.

(b) Components.

(i) The LNG when unloaded at Buyer’s Facility shall, in a gaseous state, contain not less than eighty-four molecular percentage (84.0 MOL%) of methane (C1) and, for the components and substances listed below, such LNG shall not contain more than the following:

a. Nitrogen (N2), 1.5 MOL%;

b. Ethane (C2), 11 MOL%;

c. Propane (C3), 3.5 MOL%;

d. Butanes (C4) and heavier, 2 MOL%;

e. Pentanes (C5) and heavier, 0.09 MOL%;

f. Hydrogen sulfide (H2S), 0.25 grains per 100 Standard Cubic Feet; and

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g. Total sulfur content, 1.35 grains per 100 Standard Cubic Feet.

(ii) The LNG when delivered by Seller to Buyer shall contain no water, mercury, active bacteria or bacterial agents (including sulfate reducing bacteria or acid producing bacteria) or other contaminants or extraneous material.

6.2 Off-Specification LNG

(a) Off-Spec LNG. Without prejudice to any other rights and remedies of Buyer hereunder, Buyer may refuse to take delivery of all or part of any LNG not conforming to the quality specifications set forth in Section 6.1 (“Off-Spec LNG”), subject to Buyer’s obligation under Section 6.2(b) to use reasonable endeavors to take delivery of any Cargoes which it would otherwise be entitled to reject.

(b) Notice of Off-Spec LNG. Seller shall provide notice to Buyer as soon as reasonably practicable of any existing or anticipated delivery of Off-Spec LNG, giving details of the nature and expected magnitude of the variance, the cause of the non-compliance and the probable duration thereof, including the Cargoes and Scheduled Unloading Dates to be affected thereby. If so notified, Buyer and Seller shall promptly confer to determine what steps can be reasonably taken to alleviate or eliminate the problem safely and with the least economic detriment to the Parties. If Buyer is notified by Seller prior to the commencement of unloading of a Cargo at Buyer’s Facility that the LNG is Off-Spec LNG and the quantity is delivered to Buyer’s Facility, Buyer shall use reasonable endeavors to unload such Off-Spec LNG; provided, however that Buyer shall be entitled to delay unloading of Off-Spec LNG for the period of time reasonably required for Buyer to determine whether it can take delivery of such Off-Spec LNG pursuant to this Section 6.2(b). Subject to Buyer first using its reasonable endeavors to take delivery of any Cargoes containing Off-Spec LNG, Buyer shall:

(i) notify Seller that Buyer will take delivery of some or all of the affected Cargoes, without prejudice to Buyer’s rights and remedies with respect to such Off-Spec LNG other than Buyer’s right to reject said Cargoes; or

(ii) reject all or any of the affected Cargoes, in which case: (x) Seller may dispose of such rejected LNG by sale to a third party or otherwise as determined by Seller in its sole discretion; and (y) Seller shall be liable to Buyer for non-delivery of such rejected LNG in the manner and to the extent provided in this Agreement.

(c) Seller’s Responsibility. If Buyer accepts delivery of a Cargo of Off-Spec LNG which it would otherwise be entitled to reject, Seller shall:

(i) bear the financial responsibility for all reasonable and actual incremental costs (other than capital costs) and Liabilities incurred by Buyer or any of Buyer’s Affiliates, in each case acting as a Reasonable and Prudent

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Person, in connection with receiving and treating Off-Spec LNG by such means as are appropriate, including blending such Off-Spec LNG with lower calorific value Gas or injecting nitrogen if facilities to allow for such blending or injection exist at Buyer’s Facility; and

(ii) indemnify and hold harmless Buyer, its Affiliates and their respective directors, officers and employees from any and all Liabilities, including any of same attributable to claims of any Person and any Terminal User, which arise out of, are incident to, or result from the acceptance, handling, disposal or use of Off-Spec LNG.

(d) No Continuing Waiver. Acceptance of Off-Spec LNG shall not prevent Buyer from refusing future deliveries of Off-Spec LNG. No waiver by Buyer of any default by Seller of any of the specifications set forth in this Article 6 shall ever operate as a continuing waiver of such specification or as a waiver of any subsequent default, whether of a like or different character.

(e) Extended Delivery of Off-Spec LNG. If: (i) Seller notifies Buyer pursuant to Section 6.2(b) of an anticipated delivery of two (2) or more Cargoes of Off-Spec LNG; and (ii) the Parties agree for Buyer to incur incremental capital costs at Buyer’s Facility in order to accept delivery of such Cargoes, then Seller shall, in addition to its payment and indemnification obligations under Section 6.2(c), bear the financial responsibility for and directly fund, at Buyer’s election, all such incremental capital costs.

ARTICLE 7

INVOICES AND PAYMENT

7.1 Delivery Invoices and Cargo Documents

(a) Prior to the arrival of any LNG Vessel at the Delivery Point, Seller or its representative shall furnish to Buyer any and all documentation sufficient, in Buyer’s reasonable estimation, to demonstrate that the LNG Vessel and its Cargo will properly and completely clear customs in the United States of America. Buyer shall be responsible for all costs and expenses incident to clearing customs at the Receipt Point.

(b) Promptly after Completion of Unloading of an LNG Vessel at Buyer’s Facility, Seller or its representative shall furnish to Buyer a certificate of quantity unloaded. Buyer shall, on a reasonable efforts basis within twenty-four (24) hours but in no event later than forty-eight (48) hours after Completion of Unloading, complete a laboratory analysis and calculations to determine the quality and BTU content of the LNG unloaded, in accordance with the provisions of Annex I, and shall promptly furnish to Seller or its representative a copy of the laboratory analysis with respect thereto. Upon receiving such laboratory analysis, Seller shall calculate the number of BTU unloaded and delivered, in accordance with the provisions of Annex I, and shall furnish to Buyer the details of the calculation.

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Seller shall, on a reasonable efforts basis, furnish to Buyer by e-mail or facsimile an invoice within seven (7) days after Completion of Unloading stating the amount of the Contract Price. At the same time, Seller shall send to Buyer a signed copy of the invoice. For this purpose, an e-mail or facsimile copy of an invoice shall be deemed received by Buyer on the day after it was sent or on the following Business Day if received by Buyer after 5:00 p.m. Central Time.

(c) If Buyer has not completed the above-mentioned quality analysis within the aforesaid forty-eight (48) hour period, Seller may furnish to Buyer a provisional commercial invoice based upon the typical BTU content and typical MOL composition analysis of LNG delivered from Seller’s Facilities, and such provisional invoice shall be payable on the due date specified pursuant to Section 7.3, subject only to any later adjusting payment that may be called for when the aforesaid analysis has been completed, and an appropriate invoice issued in respect thereof.

7.2 Other Invoices

Except as provided in Section 7.1, in the event that any sums of money are due from one Party to the other Party hereunder, then the Party to whom such sums of money are owed shall furnish to the other Party an invoice therefore, together with relevant supporting documents showing the basis for the calculation thereof.

7.3 Invoice Due Dates

(a) Each invoice referred to in Section 7.1 for LNG delivered to Buyer shall become due and payable by Buyer within ten (10) days following receipt of such invoice; provided that if such day is not a Business Day, it shall become due and payable on the next Business Day.

(b) Except as otherwise expressly provided in this Agreement, each invoice arising under Section 7.2 shall become due and payable by the Party receiving the invoice on or before the twentieth (20th) day after the date of receipt of such invoice; provided that if such day is not a Business Day, it shall become due and payable on the next Business Day.

(c) In the event the full amount of any invoice payable hereunder is not paid when due as provided in Sections 7.3(a) and 7.3(b), any unpaid amount thereof shall bear interest from the due date until paid at the Base Rate.

7.4 Payment

(a) Buyer shall pay or cause to be paid, on or before the due date, in U.S. dollars, all amounts that become due and payable by Buyer pursuant to Seller’s invoice issued hereunder (except that in the case of obvious error in computation the Party receiving the invoice shall pay the correct amount after disregarding such error). Such payments shall be made in immediately available funds in the United States of America to such account or accounts with such bank and in such location as shall have been designated in writing by Seller.

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(b) Seller shall pay or cause to be paid, on or before the due date, in U.S. dollars, all amounts that become due and payable by Seller pursuant to Buyer’s invoice issued hereunder (except that in the case of obvious error in computation the Party receiving the invoice shall pay the correct amount after disregarding such error). Such payments shall be made in immediately available funds in the United States of America, to such account with such bank in such location as shall have been designated in writing by Buyer.

(c) Each payment of any amount owing hereunder shall be for the full amount due, without reduction, withholding or offset for any reason (including, any exchange charges, bank transfer charges, any other fees, or Taxes, other than any Taxes for which Seller or Buyer is liable in accordance with Article 8). If Buyer is required by law to make any reduction or withholding, Buyer shall pay to Seller such amount as will result in Seller receiving the full invoiced amount after such reduction or withholding, and promptly pay to the relevant authorities the amount deducted or withheld and provide to Seller a copy of the calculation of any withholding or deduction and a receipt or other evidence of payment.

7.5 Disputed Invoices

In the event a Party disputes any invoice, it shall pay the other Party the full amount of such payment by the due date and inform the other Party in writing of the portion of the invoice in dispute and the reasons for such dispute. The Parties shall cooperate in resolving the dispute expeditiously. An invoice may be contested by the Party that received it, or modified by the Party that sent it, by written notice delivered to the other Party within a period of ninety (90) days after such receipt or sending, as the case may be. If no such notice is served, such invoice shall be deemed correct and accepted by both Parties. Promptly after resolution of any dispute as to an invoice, the amount of any overpayment or underpayment shall be paid by Seller or Buyer (as the case may be) to the other Party, together with interest thereon at the Base Rate from the date payment was due to the date of payment.

ARTICLE 8

TAXES, DUTIES AND CHARGES

8.1 Seller’s Obligations

Seller shall pay (or cause to be paid) all Taxes arising in the country where Seller’s Facilities are situated on the sale, export or transportation of LNG before delivery at the Receipt Point and all Taxes and Port Charges levied or imposed on the LNG Vessel before the Receipt Point. Seller shall indemnify Buyer in respect of any such Taxes, Port Charges, interest and penalties that Buyer is obligated to pay.

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8.2 Buyer’s Obligations

Buyer shall pay (or cause to be paid) all Taxes arising as a result of the purchase, import or resale of LNG at or after delivery at the Receipt Point. Buyer shall indemnify Seller in respect of any such Taxes, interest and penalties that Seller is obligated to pay.

8.3 Refund of Taxes

If Seller subsequently receives any refund of Taxes in respect of which Buyer has indemnified Seller pursuant to Section 8.2 above, Seller shall promptly pay such refund to Buyer. If Buyer subsequently receives any refund of Taxes in respect of which Seller has indemnified Buyer pursuant to Section 8.1 above, Buyer shall promptly pay such refund to Seller.

ARTICLE 9

LIABILITIES AND FAILURE TO PERFORM

9.1 General

Notwithstanding any other provision of this Agreement to the contrary, no Party shall be liable to the other Party for or in respect of:

(a) any consequential loss or damage, including loss of profits or business interruption; or

(b) any special, incidental or punitive damages.

suffered or incurred by the other Party or any Person resulting from breach of or failure to perform this Agreement or the breach of any representation or warranty hereunder, whether express or implied, and whether such damages are claimed under breach of warranty, breach of contract, tort, or other theory or cause of action at law or in equity, except to the extent such damages have been awarded to a third party and are subject to allocation between or among the parties to the Dispute.

9.2 Buyer’s Failure to Take Delivery of LNG Quantity

If for any reason not expressly permitted under this Agreement, other than: (i) Force Majeure; (ii) reasons attributable to Seller or any of its agents; or (iii) reasons attributable to the LNG Vessel, or its owner, operator, master or crew, Buyer fails to take delivery of a Cargo scheduled for delivery to Buyer, the Parties shall use reasonable efforts to reschedule such Cargo. If the Parties are unable to reschedule such Cargo, Seller shall use reasonable efforts to sell such Cargo to a third party. Seller shall issue to Buyer an invoice pursuant to Section 7.2 and Buyer shall pay to Seller:

(a) if Seller is able to sell such total or partial Cargo to a third party, a net amount determined by the Contract Price for such Cargo which Buyer failed to take delivery, less the actual proceeds Seller realizes from such total or partial Cargo sale to a third party, plus actual, reasonable and documented costs incurred by

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Seller in such actual sale, less any shipping cost saved in such actual sale; provided, however, that if the net amount is negative such net amount shall be retained by Seller for its own account; or

(b) if Seller is unable to sell such total or partial Cargo to a third party, an amount determined by the Contract Price for such Cargo which Buyer failed to take delivery.

This payment is intended to hold Seller harmless from Buyer’s failure to take delivery under this Section 9.2 and shall be Seller’s sole and exclusive remedy in such event.

9.3 Seller’s Failure to Deliver LNG Quantity

If for any reason not expressly permitted under this Agreement, other than: (i) Force Majeure; (ii) reasons attributable to Buyer; or (iii) reasons attributable to Buyer’s Facility, Seller fails to deliver a Cargo scheduled for delivery to Buyer (provided that such Cargo is included in the Three Month Unloading Schedule pursuant to Section 2.2), the Parties shall use reasonable efforts to reschedule such Cargo. If the Parties are unable to reschedule such Cargo, then Buyer may notify Seller that it requires Seller not to deliver such Cargo and Buyer shall issue to Seller an invoice pursuant to Section 7.2 and Seller shall pay to Buyer an amount equal to the Cargo multiplied by twelve percent (12%) multiplied by the Henry Hub Price that would have been in effect had the Cargo been delivered, as liquidated damages for such failure to deliver. This payment is intended to hold Buyer harmless from Seller’s failure to deliver under this Section 9.3 and shall be Buyer’s sole and exclusive remedy in such event.

9.4 Minimum LNG Quantity

If for any reason not expressly permitted under this Agreement, other than: (i) Force Majeure; (ii) reasons attributable to Buyer, its Affiliates or their respective agents; or (iii) reasons attributable to Buyer’s Facility, Seller fails to deliver the Minimum LNG Quantity for any year during the Term, then Seller shall be required to pay Buyer an amount equal to the Deemed Contract Price multiplied by twelve (12%) percent, as liquidated damages for such failure to deliver. For purposes hereof, the “Deemed Contract Price” shall be equal to the Minimum LNG Quantity multiplied by the annual average of the monthly closing prices in US$/MMBTU as published by the New York Mercantile Exchange for the Henry Hub Natural Gas futures contract for Natural Gas to be delivered during such period.

9.5 Duty to Mitigate Damages

Each Party acknowledges that it has a duty to mitigate damages and that it shall use good faith efforts to find a substitute buyer or seller, as the case may be, in the event that the other Party does not perform its obligations hereunder.

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ARTICLE 10

FORCE MAJEURE

10.1 Events of Force Majeure

Neither Party shall be liable to the other for any delay or failure in performance hereunder if and to the extent such delay or failure is a result of Force Majeure. Subject to the provisions of this Article 10, the term “Force Majeure” shall mean any cause not within the control of the Party claiming suspension, and which by the exercise of due diligence, such Party has been unable to prevent or overcome, including without limitation acts of God, government, or a public enemy: strikes, lockout, or other industrial disturbances; wars, blockades or civil disturbances of any kind; epidemics, Adverse Weather Conditions, the removal of an LNG Vessel from service due to arrest or seizure, loss, serious accidental damage or other serious failure, fires, explosions, arrests and restraints of governments or people; freezing of, breakage or accident to, or serious accidental damage to or other serious failure to Seller’s Facilities or Buyer’s Facility that is the scheduled Receipt Point, or the necessity for making repairs or alterations to tanks, machinery or lines of pipe, and events of majeure as defined and in accordance with the terminal use agreement that Buyer has in place with Buyer’s Facility. Nothing in this Article 10 shall be construed to require a Party to observe a higher standard of conduct than that required of a Reasonable and Prudent Person as a condition to claiming the existence of Force Majeure. Notwithstanding the foregoing, in no event shall the following events and circumstances be considered an event of Force Majeure:

(a) a Party’s inability economically to perform its obligations under this Agreement;

(b) the failure of Buyer’s or its Affiliate’s customers to receive or pay for Gas; and

10.2 Limitation on Scope of Force Majeure for Customer

Notwithstanding the provisions of Section 10.1, an event of Force Majeure shall not relieve, suspend, or otherwise excuse a Party from performing any obligation to indemnify, reimburse, hold harmless or otherwise make payments when due under this Agreement.

10.3 Notice

A Force Majeure event shall take effect at the moment such an event or circumstance occurs. Upon the occurrence of a Force Majeure event that prevents, interferes with or delays the performance by Buyer or Seller, in whole or in part, of any of its obligations hereunder, the Party affected shall give notice thereof to the other Party describing such event and stating the obligations the performance of which are affected (either in the original or in supplemental notices) and stating, as applicable:

(a) the estimated period during which performance may be prevented, interfered with or delayed, including, to the extent known or ascertainable, the estimated extent of such reduction in performance;

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(b) the particulars of the program to be implemented to resume normal performance hereunder;

(c) the anticipated portion of the LNG Quantities for a Contract Year that will not be made available or received, as the case may be, by reason of Force Majeure; and

(d) where Section 10.7 applies, the quantity of services that Buyer reasonably expects to allocate to Seller.

Such notices shall thereafter be updated at least monthly during the period of such claimed Force Majeure specifying the actions being taken to remedy the circumstances causing such Force Majeure.

10.4 Measures

In order to resume normal performance of this Agreement within the shortest time practicable, the Party affected by the Force Majeure shall take all measures that are commercially reasonable under the circumstances, taking into account the consequences resulting from such event of Force Majeure. Prior to resumption of normal performance, the Parties shall continue to perform their obligations under this Agreement to the extent not excused by such event of Force Majeure.

10.5 No Extension of Term

The Term shall not be extended as a result of or by the duration of an event of Force Majeure, except that the Term shall be extended for periods of Force Majeure in the event that Buyer extends the term applicable to other Terminal Users similarly affected by such event of Force Majeure.

10.6 Settlement of Industrial Disturbances

Settlement of strikes, lockouts, or other industrial disturbances shall be entirely within the discretion of the Party experiencing such situations, and nothing herein shall require such Party to settle industrial disputes by yielding to demands made on it when it considers such action inadvisable.

10.7 Allocation of Services

If, as a result of an event of Force Majeure, Buyer is unable to meet its contractual obligations to Seller and any Terminal Users, Buyer shall allocate the available capability of Buyer to perform activities similar to the services to Seller and Terminal Users in a reasonable and equitable manner.

10.8 Extended Period of Force Majeure

If a Party’s performance under this Agreement is suspended due to an event of Force Majeure in excess of eighteen (18) months from the date that notice of such event is given, and so long as such event is continuing, either Party, in its sole discretion, may

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terminate this Agreement by written notice to the other Party, and neither Party shall have any further liability to the other Party in respect of this Agreement except for the rights and remedies previously accrued.

ARTICLE 11

ASSIGNMENT

11.1 Generally

Buyer may not assign either this Agreement or any rights or obligations hereunder without the prior approval of Seller, and Seller shall not be unreasonable in withholding such approval. Seller may not assign either this Agreement or any rights or obligations hereunder without the prior approval of Buyer, and Buyer shall not be unreasonable in withholding such approval. No assignment shall serve as a novation to this Agreement.

11.2 Permitted Assignments

Each Party shall be entitled to assign, mortgage, or pledge all or any of its rights, interests, and benefits hereunder to secure payment of any indebtedness incurred or to be incurred by such Party. The non-assigning Party shall provide to the lenders to whom such indebtedness is owed a consent to assignment or similar document in form and substance reasonably satisfactory to the non-assigning Party and customary for similar financing transactions.

ARTICLE 12

TERMINATION

12.1 Early Termination Events

(a) Termination for non-payment. Either Party may terminate this Agreement if payments due under this Agreement are not paid within thirty (30) days of a written demand therefore.

(b) Termination for Insolvency. Either Party may terminate this Agreement if the other Party becomes Bankrupt.

(c) Termination for non-performance. Seller may terminate this Agreement if Buyer consistently and materially fails to perform its purchase obligations under this Agreement.

(d) Option to Terminate Following a Change in Control. Upon the occurrence of a Change in Control, Seller shall have the option, exercisable only upon written notice to Buyer within ninety (90) days of the occurrence of such Change of Control, to terminate this Agreement upon thirty (30) days advance written notice to Buyer. This option to terminate shall expire and shall be of no further force and effect if not exercised as provided above within the ninety (90) day period.

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12.2 Notice

Buyer or Seller, as the case may be, shall give notice of its exercise of any termination right hereunder to the other Party.

12.3 Consequences of Termination

Termination of this Agreement under this Article 12 or any other provision of this Agreement shall be without prejudice to any other rights and remedies of either Party arising hereunder or by law or otherwise which arose or accrued prior to or by reason of default of either Party, provided, however, that in no event shall Seller be entitled to recover damages or pursue any other remedy against Buyer in relation to services which would have been performed by Buyer after the date of termination by Seller.

12.4 Consequences of a Share Buyout

(a) The provisions of this Section 12.4 shall apply in the event that either party (or their successors or assigns) to that certain Amended and Restated Shareholders Agreement dated February ___, 2007 between Mercuria Energy Holding B.V. and Cheniere LNG Services, Inc. (the “Shareholders Agreement”) acquires all of the outstanding shares of J&S Cheniere S.A. held by such party on the effective date of the Shareholders Agreement and such acquisition does not occur due to a Change of Control (the “Share Buyout”)

(b) Commencing as of the effective date of the Share Buyout, the provisions of Clause C.2.(a) are hereby deleted and shall be without further force and effect.

(c) For all purposes of this Agreement, following the occurrence of a Share Buyout, the term: (i)LNG Quantity shall mean seventy eight million four hundred seventy five thousand (78,475,000) MMBTU (or the pro-rata portion of such amount in the event of a partial Contract Year); and (ii) Minimum LNG Quantity shall hereby be deleted from this Agreement.

(d) Commencing as of the effective date of the Share Buyout, Seller agrees to deliver and sell to Buyer and Buyer agrees to purchase, on an annual basis, the LNG Quantity at the Contract Price as determined in accordance with Clause D for each cargo delivered in accordance with this Agreement as midifed by this Section 12.4.

(e) Commencing as of the effective date of the Share Buyout, Section 9.4 of this Agreement shall be amended and restated to read as follows:

“If for any reason not expressly permitted under this Agreement, other than: (i) Force Majeure; or (ii) reasons attributable to Buyer, the Sabine Pass Terminal or their respective agents; Seller fails to deliver the LNG Quantity for any Contract Year during the Term, then Seller shall be required to pay Buyer an amount equal to the Deemed Contract Price multiplied by twelve (12%) percent, as liquidated damages for such failure to deliver. For purposes hereof, the “Deemed Contract

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Price” shall be equal to the difference between the LNG Quantity less the quantity of LNG actually delivered and sold by Seller to Buyer hereunder during such Contract Year (the “Shortfall”) multiplied by the annual average of the monthly closing prices in US$/MMBTU as published by the New York Mercantile Exchange for the Henry Hub Natural Gas futures contract for Natural Gas.

“For the three (3) month period following the Contract Year during which the Shortfall occurred, Seller will be entitled to seek to re-schedule the Shortfall for delivery and sale to Buyer hereunder during such three (3) month period; provided, however, that (i) Seller shall have firmly scheduled at least twenty-five percent (25%) of the LNG Quantity for delivery during such three (3) month period, and (ii) Buyer’s Facility has available the required Unloading Dates and is otherwise operationally capable to accept such Shortfall.”

ARTICLE 13

APPLICABLE LAW

The substantive laws of the State of New York, United States of America, exclusive of any conflicts of laws principles that could require the application of any other law, shall govern this Agreement for all purposes, including the resolution of all Disputes between or among the Parties.

ARTICLE 14

DISPUTE RESOLUTION

14.1 Dispute Resolution

(a) Arbitration. Any Dispute (other than a Dispute regarding measurement under Annex I) shall be exclusively and definitively resolved through final and binding arbitration, it being the intention of the Parties that this is a broad form arbitration agreement designed to encompass all possible disputes.

(b) Rules. The arbitration shall be conducted in accordance with the International Arbitration Rules (the “Rules”) of the American Arbitration Association (“AAA”) (as then in effect).

(c) Number of Arbitrators. The arbitral tribunal (“Tribunal”) shall consist of three (3) arbitrators, who shall endeavor to complete the final hearing in the arbitration within six (6) months after the appointment of the last arbitrator.

(d) Method of Appointment of the Arbitrators. If there are only two (2) parties to the Dispute, then each party to the Dispute shall appoint one (1) arbitrator within thirty (30) days of the filing of the arbitration, and the two arbitrators so appointed shall select the presiding arbitrator within thirty (30) days after the latter of the two arbitrators has been appointed by the parties to the Dispute. If a party to the Dispute fails to appoint its Party-appointed arbitrator or if the two Party-appointed arbitrators cannot reach an agreement on the presiding arbitrator within the

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applicable time period, then the AAA shall serve as the appointing authority and shall appoint the remainder of the three arbitrators not yet appointed. If the arbitration is to be conducted by three arbitrators and there are more than two parties to the Dispute, then within thirty (30) days of the filing of the arbitration, all claimants shall jointly appoint one arbitrator and all respondents shall jointly appoint one arbitrator, and the two arbitrators so appointed shall select the presiding arbitrator within thirty (30) days after the latter of the two arbitrators has been appointed by the parties to the Dispute. For the purposes of appointing arbitrators under this Article 14: (a) Seller and all persons whose interest in this Agreement derives from them shall be considered as one Party; and (b) Buyer and all persons whose interest in this Agreement derives from Buyer shall be considered as one Party. If either all claimants or all respondents fail to make a joint appointment of an arbitrator, or if the Party-appointed arbitrators cannot reach an agreement on the presiding arbitrator within the applicable time period, then the AAA as the appointing authority shall make the prescribed appointment.

(e) Consolidation. If the Parties initiate multiple arbitration proceedings under this Agreement, the subject matters of which are related by common questions of law or fact and which could result in conflicting awards or obligations, then either Party may request prior to the appointment of the arbitrators for such multiple or subsequent disputes that all such proceedings be consolidated into a single arbitral proceeding. Such request shall be directed to the AAA, which shall consolidate appropriate proceedings into a single proceeding unless consolidation would result in undue delay for the arbitration of the Disputes.

(f) Place of Arbitration. Unless otherwise agreed by all parties to the Dispute, the place of arbitration shall be New York, New York.

(g) Language. The arbitration proceedings shall be conducted in the English language, and the arbitrators shall be fluent in the English language.

(h) Entry of Judgment. The award of the arbitral tribunal shall be final and binding. Judgment on the award of the arbitral tribunal may be entered and enforced by any court of competent jurisdiction. The Parties agree that service of process for any action to enforce an award may be accomplished according to the procedures of Article 17, as well as any other procedure authorized by law.

(i) Notice. All notices required for any arbitration proceeding shall be deemed properly given if given in accordance with Article 17.

(j) Qualifications and Conduct of the Arbitrators. All arbitrators shall be and remain at all times wholly impartial, and, once appointed, no arbitrator shall have any ex parte communications with any of the parties to the Dispute concerning the arbitration or the underlying Dispute other than communications directly concerning the selection of the presiding arbitrator, where applicable.

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(k) Interim Measures. Any party to the Dispute may apply to any federal court of competent jurisdiction situated in the Borough of Manhattan, New York, or , if any federal court declines to exercise or does not have jurisdiction, in any New York state court in the Borough of Manhattan for interim measures: (i) prior to the constitution of the arbitral tribunal (and thereafter as necessary to enforce the arbitral tribunal’s rulings); or (ii) in the absence of the jurisdiction of the arbitral tribunal to rule on interim measures in a given jurisdiction. The Parties agree that seeking and obtaining such interim measures shall not waive the right to arbitration. The arbitrators (or in an emergency the presiding arbitrator acting alone in the event one or more of the other arbitrators is unable to be involved in a timely fashion) may grant interim measures including injunctions, attachments and conservation orders in appropriate circumstances, which measures may be immediately enforced by court order. Hearings on requests for interim measures may be held in person, by telephone, by video conference or by other means that permit the parties to the Dispute to present evidence and arguments.

(l) Costs and Attorneys’ Fees. The arbitral tribunal is authorized to award costs of the arbitration in its award, including: (a) the fees and expenses of the arbitrators; (b) the costs of assistance required by the tribunal, including its experts; (c) the fees and expenses of the administrator; (d) the reasonable costs for legal representation of a successful Party; and (e) any such costs incurred in connection with an application for interim or emergency relief and to allocate those costs between the parties to the Dispute. The costs of the arbitration proceedings, including attorneys’ fees, shall be borne in the manner determined by the arbitral tribunal.

(m) Interest. The award shall include pre-award and post-award interest, as determined by the arbitral award, from the date of any default or other breach of this Agreement until the arbitral award is paid in full. Interest shall accrue at the Base Rate.

(n) Currency of Award. The arbitral award shall be made and payable in United States dollars, free of any tax or other deduction.

(o) Waiver of Challenge to Decision or Award. To the extent permitted by law, the Parties hereby waive any right to appeal from or challenge any arbitral decision or award, or to oppose enforcement of any such decision or award before a court or any governmental authority, except with respect to the limited grounds for modification or non-enforcement provided by any applicable arbitration statute or treaty.

(p) Confidentiality. Any arbitration or expert determination relating to a Dispute (including a settlement resulting from an arbitral award, documents exchanged or produced during an arbitration proceeding, and memorials, briefs or other documents prepared for the arbitration) shall be confidential and may not be disclosed by the Parties, their employees, officers, directors, counsel, consultants, and expert witnesses, except (in accordance with Article 15) to the extent

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necessary to enforce this Section 14.1 or any arbitration award, to enforce other rights of a party to the Dispute, or as required by law; provided, however, that breach of this confidentiality provision shall not void any settlement, expert determination or award.

14.2 Expert Determination

(a) General. In the event of any disagreement between the Parties regarding a measurement under Annex I (a “Measurement Dispute”), the Parties hereby agree that such Measurement Dispute shall be resolved by an expert selected as provided in this Section 14.2. The expert is not an arbitrator of the Measurement Dispute and shall not be deemed to be acting in an arbitral capacity. The Party desiring an expert determination shall give the other Party to the Measurement Dispute notice of the request for such determination. If the Parties to the Measurement Dispute are unable to agree upon an expert within ten (10) days after receipt of the notice of request for an expert determination, then, upon the request of any of the Parties to the Measurement Dispute, the International Centre for Expertise of the International Chamber of Commerce shall appoint such expert and shall administer such expert determination through the ICC’s Rules for Expertise. The expert shall be and remain at all times wholly impartial, and, once appointed, the expert shall have no ex parte communications with any of the Parties to the Measurement Dispute concerning the expert determination or the underlying Measurement Dispute. The Parties to the Measurement Dispute shall cooperate fully in the expeditious conduct of such expert determination and provide the expert with access to all facilities, books, records, documents, information and personnel necessary to make a fully informed decision in an expeditious manner. Before issuing a final decision, the expert shall issue a draft report and allow the Parties to the Measurement Dispute to comment on it. The expert shall endeavor to resolve the Measurement Dispute within thirty (30) days (but no later than sixty (60) days) after his appointment, taking into account the circumstances requiring an expeditious resolution of the matter in dispute.

(b) Final and Binding. The expert’s decision shall be final and binding on the Parties to the Measurement Dispute unless challenged in an arbitration pursuant to Section 14.1 within thirty (30) days of the date the expert’s decision. If challenged, (i) the decision shall remain binding and be implemented unless and until finally replaced by an award of the arbitrators; (ii) the decision shall be entitled to a rebuttable presumption of correctness; and (iii) the expert shall not be appointed in the arbitration as an arbitrator or as advisor to either Party without the written consent of both Parties.

(c) Arbitration of Expert Determination. In the event that a Party requests expert determination for a Measurement Dispute which raises issues that require determination of other matters in addition to correct measurement under Annex I, then either Party may elect to refer the entire Measurement Dispute for arbitration under Section 14.1. In such case, the arbitrators shall be competent to make any measurement determination that is part of a Dispute. An expert determination not referred to arbitration shall proceed and shall not be stayed during the pendency of arbitration.

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ARTICLE 15

CONFIDENTIALITY

15.1 Confidentiality Obligation

Neither this Agreement nor information or documents that come into the possession of a Party by means of the other Party in connection with the performance of this Agreement may be used or communicated to Persons (other than the Parties) without the mutual written agreement of the Parties, except that either Party shall have the right to disclose such information or documents without obtaining the other Party’s prior consent in any of the situations described below:

(a) to accountants, other professional consultants or underwriters, provided such disclosure is solely to assist the purpose for which the aforesaid were so engaged and further provided that such Persons agree to hold such information or documents under terms of confidentiality equivalent to this Section 15.1, and for the benefit of the Parties;

(b) to Lenders and other providers or prospective providers of finance to Buyer in relation to Buyer’s Facility, provided that such Persons agree to hold such information or documents confidential, and for the benefit of the Parties, for a period of at least three (3) years (excepting information in connection with the Contract Price, which shall be held confidential during the Term);

(c) to bona fide prospective purchasers of all or a part of a Party’s or its Affiliate’s business, and bona fide prospective assignees of all or part of a Party’s interest in this Agreement, provided that such Persons agree to hold such information or documents under terms of confidentiality equivalent to this Section 15.1, and for the benefit of the Parties;

(d) to legal counsel, provided such disclosure is solely to assist the purpose for which the aforesaid were so engaged;

(e) if required by any court of law or any law, rule, or regulation, or if requested by a Governmental Authority (including the United States Securities and Exchange Commission) having or asserting jurisdiction over a Party and having or asserting authority to require such disclosure in accordance with that authority, or pursuant to the rules of any recognized stock exchange or agency established in connection therewith. Seller further acknowledges and agrees that complete copies of this Agreement, with attachments, and any and all related agreements and material amendments hereto may be filed by Cheniere Energy, Inc. with the United States Securities and Exchange Commission as material agreements or amendments in accordance with applicable securities laws and regulations;

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(f) to prospective assignees permitted under Section 11.2, to prospective and actual LNG suppliers, in each case only to the extent required for the execution and/or administration of such contracts, and provided that such Persons agree to hold such information or documents under terms of confidentiality equivalent to this Section 15.1, and for the benefit of the Parties;

(g) to its Affiliates, its shareholders and partners, or its shareholders’ and partners’ Affiliates, provided that such recipient entity has a bona fide business need for such information and agrees to hold such information or documents under terms of confidentiality equivalent to this Section 15.1;

(h) to any Governmental Authority to the extent such disclosure assists Buyer and Seller in obtaining Approvals;

(i) to an expert in connection with the resolution of a Dispute pursuant to Section 14.2 or to an arbitration tribunal in connection with the resolution of a Dispute under Section 14.1; and

(j) to the extent any such information or document has entered the public domain other than through the fault or negligence of the Party making the disclosure.

15.2 Public Announcements

Neither Party may issue or make any public announcement, press release or statement regarding this Agreement unless, prior to the release of the public announcement, press release or statement, such Party furnishes the other Party with a copy of such announcement, press release or statement, and obtains the approval of the other Party, such approval not to be unreasonably withheld; provided that, notwithstanding any failure to obtain such approval, no Party shall be prohibited from issuing or making any such public announcement, press release or statement if in the sole discretion of the disclosing Party it is deemed appropriate to do so in order to comply with the applicable laws, rules or regulations of any Governmental Authority, legal proceedings or stock exchange having jurisdiction over such Party.

ARTICLE 16

REPRESENTATIONS AND WARRANTIES

As of the date hereof and until the expiration of this Agreement, each Party represents and warrants to the other Party that:

(a) it is and shall remain duly formed and in good standing under the laws of the jurisdiction of its organization;

(b) it has the requisite power, authority and legal right to execute and deliver, and to perform its obligations under, this Agreement;

(c) it has not, in connection with the execution of this Agreement, incurred any liability to any financial advisor, broker or finder for any financial advisory, brokerage, finder’s or similar fee or commission for which it or any of its Affiliates could be liable;

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(d) neither the execution, delivery nor performance of this Agreement violates or will violate, results or will result in a breach of or constitutes or will constitute a default under any provision of it’s organizational documents, any law, judgment, order, decree, rule or regulation of any court, administrative agency or other instrumentality of any Governmental Authority or of any other material agreement or instrument to which it is a party;

(e) its obligations under this Agreement constitute its legal, valid and binding obligations, enforceable in accordance with its terms (subject to applicable bankruptcy, reorganization, insolvency, moratorium or similar laws affecting creditors’ rights regardless of whether enforcement is sought in a proceeding in equity or at law and an implied covenant of good faith and fair dealing);

(f) all governmental and other authorizations, approvals, consents, notices and filings that are required to have been obtained or submitted by it with respect to this Agreement have been obtained or submitted and are in full force and effect, and all conditions of any such authorizations, approvals, consents, notices and filings have been complied with.

ARTICLE 17

NOTICES

Except as otherwise specifically provided, all notices authorized or required between the Parties by any of the provisions of this Agreement shall be in writing (in English) and delivered in person or by courier service or by any electronic means of transmitting written communications which provides written confirmation of complete transmission, and addressed to such Party. Oral communication does not constitute notice for purposes of this Agreement, and e-mail addresses and telephone numbers for the Parties are listed as a matter of convenience only. The foregoing notwithstanding, notices given from LNG Vessels at sea may be given by radio, and notices required under Article 2 may be given by e-mail. A notice given under any provision of this Agreement shall be deemed delivered only when received by the Party to whom such notice is directed, and the time for such Party to deliver any notice in response to such originating notice shall run from the date the originating notice is received. “Received” for purposes of this Article 17 shall mean actual delivery of the notice, or delivery of the notice to the address of the Party specified below or, in the event notice was given by radio from an LNG Vessel at sea, actual receipt of the communication by radio, or to be thereafter notified in accordance with this Article 17. Each Party shall have the right to change its address at any time and/or designate that copies of all such notices be directed to another Person at another address by giving written notice thereof to the other Party.

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ARTICLE 18

MISCELLANEOUS

18.1 Amendments

This Agreement may not be amended, modified, varied or supplemented except by an instrument in writing signed by Buyer and Seller.

18.2 Approvals

Each Party shall use reasonable endeavors to maintain in force all Approvals necessary for its performance under this Agreement. Seller and Buyer shall cooperate fully with each other wherever necessary for this purpose.

18.3 Successors and Assigns

This Agreement shall inure to the benefit of and be binding upon the respective successors and permitted assigns of the Parties.

18.4 Waiver

No failure to exercise or delay in exercising any right or remedy arising from this Agreement shall operate or be construed as a waiver of such right or remedy. Performance of any condition or obligation to be performed hereunder shall not be deemed to have been waived or postponed except by an instrument in writing signed by the Party who is claimed to have granted such waiver or postponement. No waiver by either Party shall operate or be construed as a waiver in respect of any failure or default not expressly identified by such written waiver, whether of a similar or different character, and whether occurring before or after that waiver.

18.5 No Third Party Beneficiaries

The interpretation of this Agreement shall exclude any rights under legislative provisions conferring rights under a contract to Persons not a party to that contract. Nothing in this Agreement shall otherwise be construed to create any duty to, or standard of care with reference to, or any liability to, any Person other than a Party.

18.6 Rules of Construction

Each provision of this Agreement shall be construed as though all Parties participated equally in the drafting of the same. Consequently, the Parties acknowledge and agree that any rule of construction that a document is to be construed against the drafting Party shall not be applicable to this Agreement.

18.7 Survival of Rights

Any termination or expiration of this Agreement shall be without prejudice to any rights, remedies, obligations and liabilities which may have accrued to a Party pursuant to this

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Agreement or otherwise under applicable law. All rights or remedies which may have accrued to the benefit of either Party (and any of this Agreement’s provisions necessary for the exercise of such accrued rights or remedies) prior to the termination or expiration of this Agreement shall survive such termination or expiration. Furthermore, the provisions of Articles 7, 8, 9, 12, 13, 14, 15, 16, 17 and 18 shall survive the termination or expiration of this Agreement.

18.8 Rights and Remedies

Except where this Agreement expressly provides to the contrary, the rights and remedies contained in this Agreement are cumulative and not exclusive of any rights and remedies provided by law.

18.9 Interpretation

(a) Headings. The topical headings used in this Agreement are for convenience only and shall not be construed as having any substantive significance or as indicating that all of the provisions of this Agreement relating to any topic are to be found in any particular Article or that an Article relates only to the topical heading.

(b) Singular and Plural. Reference to the singular includes a reference to the plural and vice versa.

(c) Gender. Reference to any gender includes a reference to all other genders.

(d) Article. Unless otherwise provided, reference to any Article, Section, Annex or Exhibit means an Article, Section, Annex or Exhibit of this Agreement. In addition, reference to a Clause means a reference to a Clause in Part One and reference to an Article or Section means a reference to an Article or Section of Part Two.

(e) Include. The words “include” and “including” shall mean include or including without limiting the generality of the description preceding such term and are used in an illustrative sense and not a limiting sense.

(f) Time Periods. References to “day,” “month,” “quarter” and “year” shall, unless otherwise stated or defined, mean a day, month, quarter and year of the Gregorian calendar, respectively. For the avoidance of doubt, a “day” shall commence at 24:00 midnight.

(g) Statutory References. Unless the context otherwise requires, any reference to a statutory provision is a reference to such provision as amended or re-enacted or as modified by other statutory provisions from time to time and includes subsequent legislation and regulations made under the relevant statute.

(h) Currency. References to United States dollars shall be a reference to the lawful currency from time to time of the United States of America.

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18.10  Disclaimer of Agency

The rights, duties, obligations and liabilities of the Parties under this Agreement shall be individual, not joint or collective. It is not the intention of the Parties to create, nor shall this Agreement be deemed or construed to create, nor shall the Parties report for any purpose any transaction occurring pursuant to this Agreement as: (a) a partnership, joint venture or other association or a trust; or (b) a lease or sales transaction with respect to any portion of Buyer’s Facility. This Agreement shall not be deemed or construed to authorize any Party to act as an agent, servant or employee for the other Party for any purpose whatsoever except as explicitly set forth in this Agreement. In their relations with each other under this Agreement, the Parties shall not be considered fiduciaries.

18.11  No Sovereign Immunity

Any Party that now or hereafter has a right to claim sovereign immunity for itself or any of its assets hereby waives any such immunity to the fullest extent permitted by the laws of any applicable jurisdiction. This waiver includes immunity from: (a) any expert determination or arbitration proceeding commenced or to be commenced pursuant to this Agreement; (b) any judicial, administrative or other proceedings to aid the expert determination or arbitration commenced pursuant to this Agreement; and (c) any effort to confirm, enforce, or execute any decision, settlement, award, judgment, service of process, execution order or attachment (including pre-judgment attachment) that results from an expert determination, mediation, arbitration or any judicial or administrative proceedings commenced pursuant to this Agreement. Each Party acknowledges that its rights and obligations hereunder are of a commercial and not a governmental nature.

18.12  Severance of Invalid Provisions

If and for so long as any provision of this Agreement shall be deemed to be judged invalid for any reason whatsoever, such invalidity shall not affect the validity or operation of any other provision of this Agreement except only so far as shall be necessary to give effect to the construction of such invalidity, and any such invalid provision shall be deemed severed from this Agreement without affecting the validity of the balance of this Agreement.

18.13  Compliance with Laws

In performance of their respective obligations under this Agreement, each Party agrees to comply with all applicable laws, statutes, rules, regulations, judgments, decrees, injunctions, writs and orders, and all interpretations thereof, of all Governmental Authorities having jurisdiction over such Party.

18.14  Expenses

Each Party shall be responsible for and bear all of its own costs and expenses incurred in connection with the preparation and negotiation of this Agreement.

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18.15  Audit Rights

Each Party shall record and keep accurate books of account of all sales and other evidence of transactions under this Agreement. All records relating to the transactions contemplated by this Agreement, including any stored electronically, shall be kept by each Party for two (2) years at such Party’s office and shall be made available to the other Party for inspection at such offices upon reasonable notice during each Party’s regular business hours.

18.16  Scope

This Agreement constitutes the entire agreement between the Parties relating to the subject matter hereof and supersedes and replaces any provisions on the same subject contained in any other agreement between the Parties, whether written or oral, prior to the date of the original execution hereof.

18.17  Counterpart Execution

This Agreement may be executed in any number of counterparts and each such counterpart shall be deemed an original Agreement for all purposes; provided that no Party shall be bound to this Agreement unless and until both Parties have executed a counterpart. For purposes of assembling all counterparts into one document, Seller is authorized to detach the signature page from one or more counterparts and, after signature thereof by the respective Party, attach each signed signature page to a counterpart.

18.18  No Conflicts / Foreign Corrupt Practices Act/International Boycott

Seller hereby agrees as follows: (A) it shall not and shall provide that its employees and agents shall not: (i) pay any commissions or fees or grant any rebates to any employee of Buyer and its Affiliates; (ii) favor employees or officers of Buyer and its Affiliates with gifts or entertainment of a significant value or cost; or (iii) enter into any business arrangements with employees or officers of Buyer and its Affiliates: (B) it shall and shall cause each of its agents and employees, if any, whether acting in the United States or outside the United States, to comply with all provisions of the Foreign Corrupt Practices Act of the United States (15 U.S.C. § 78dd-l and 2) and shall not take any action that could result in Cheniere Energy, Buyer or any of their respective Affiliates becoming subject to any action, penalty or loss of benefits under such Act; and ( C) it will not agree to participate in an international boycott described in Section 999 of the Internal Revenue Code of 1986, as amended. Furthermore, Seller shall notify Buyer if it receives a request to participate in an international boycott by any vendor or potential vendor, as required under Section 999(a)(2).

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Exhibit B

LNG TERMINAL USE AGREEMENT

BETWEEN

J&S CHENIERE S.A.

and

SABINE PASS LNG, L.P.

Dated                             

TABLE OF CONTENTS

Part One		PRINCIPAL COMMERCIAL TERMS AND CONDITIONS	i
	A.	Term	i
	B.	Services Quantity	ii
	C.	Fees and Retainage	ii
	D.	Notices	iii
	E.	Other Customers	iii
	F.	Assignment	iii
	G.	Customer Cooperation Regarding SABINE Financing	iii
PART TWO		GENERAL TERMS AND CONDITIONS	1
Article 1		DEFINITIONS	1
Article 2		SERVICES AND SCOPE	8
	2.1	Services to be Provided by SABINE	8
	2.2	Additional Services	9
	2.3	Activities Outside Scope of this Agreement	9
Article 3		SALE AND PURCHASE OF SERVICES	10
	3.1	Services	10
	3.2	Customer’s Use of Services Quantity	10
	3.3	No Pre-Delivery Right	11
	3.4	Failure to Take Delivery of Gas at Delivery Point	11
	3.5	Sabine Pass Services Manual	11
Article 4		COMPENSATION FOR SERVICES	12
	4.1	Fee	12
	4.2	Taxes and New Regulatory Costs	12
	4.3	Services Unavailability	13
	4.4	Services Provided to Other Customers	13
Article 5		SCHEDULING	13
	5.1	Annual Delivery Program	13
	5.2	Three Month Schedules	16
	5.3	Gas Delivery	17
	5.4	Standard	18
	5.5	Scheduling Representative	18
	5.6	Scheduling Coordination Among Customer and Other Customers	18

I

Article 6		COMMERCIAL START DATE	19
Article 7		SABINE PASS FACILITY	19
	7.1	Sabine Pass Facility	19
	7.2	Compatibility of Sabine Pass Facility with LNG Vessels	21
	7.3	Customer Inspection Rights	22
Article 8		TRANSPORTATION AND UNLOADING	22
	8.1	LNG Vessels	22
	8.2	Sabine Pass Marine Operations Manual	25
	8.3	LNG Vessel Inspections; Right to Reject LNG Vessel	25
	8.4	Advance Notices Regarding LNG Vessel and Cargoes	26
	8.5	Notice of Readiness	28
	8.6	Berthing Assignment	28
	8.7	Unloading Time	29
	8.8	Unloading at the Sabine Pass Facility	31
	8.9	LNG Vessel Not Ready for Unloading; Excess Berth Time	31
Article 9		RECEIPT OF LNG	32
	9.1	Title, Custody and Risk of Loss	32
	9.2	No Encumbrance	33
	9.3	Receipt of LNG	33
	9.4	Quality and Measurement of Customer’s LNG	33
	9.5	Off-Specification LNG	34
Article 10		REDELIVERY OF GAS	35
	10.1	General	35
	10.2	Customer’s Responsibility	36
	10.3	Specifications and Measurement of Gas at the Delivery Point	37
	10.4	Nonconforming Gas	38
Article 11		PAYMENT	38
	11.1	Monthly Statements	38
	11.2	Other Statements	39
	11.3	Adjustments, Audit	39
	11.4	Payment Due Dates	40
	11.5	Payment	40
	11.6	Nonpayment	40
	11.7	Disputed Statements	41
	11.8	Final Settlement	41

II

Article 12		DUTIES, TAXES AND OTHER GOVERNMENTAL CHARGES	42
Article 13		INSURANCE	42
	13.1	SABINE’s Insurance	42
	13.2	Customer’s Insurance	43
	13.3	Port Liability Agreement	43
Article 14		LIABILITIES	44
	14.1	Limitation of Liability of SABINE	44
	14.2	Consequential Loss or Damage	44
	14.3	Parties’ Liability	45
Article 15		FORCE MAJEURE	45
	15.1	Events of Force Majeure	45
	15.2	Limitation on Scope of Force Majeure for Customer	45
	15.3	Notice	45
	15.4	Measures	46
	15.5	No Extension of Term	46
	15.6	Settlement of Industrial Disturbances	46
	15.7	Allocation of Services	46
Article 16		CURTAILMENT OF SERVICES OR TEMPORARY DISCONTINUATION OF SERVICES	47
	16.1	Scheduled Curtailment or Temporary Discontinuation of Services	47
	16.2	Unscheduled Curtailment or Temporary Discontinuation of Services	47
Article 17		ASSIGNMENT	47
	17.1	Restrictions on Assignment	47
	17.2	Permitted Assignments	48
	17.3	Assignment as Novation	49
Article 18		TERMINATION	50
	18.1	Early Termination Events	50
	18.2	Other Termination Provisions	51
	18.3	Consequences of Termination	51
Article 19		APPLICABLE LAW	51
Article 20		DISPUTE RESOLUTION	51
	20.1	Dispute Resolution	51
	20.2	Expert Determination	54

III

Article 21		CONFIDENTIALITY	55
	21.1	Confidentiality Obligation	55
	21.2	Public Announcements	56
Article 22		REPRESENTATIONS AND WARRANTIES	56
	22.1	Representations and Warranties of Customer	57
	22.2	Representations and Warranties of SABINE	58
Article 23		NOTICES	57
Article 24		MISCELLANEOUS	58
	24.1	Amendments	58
	24.2	Approvals	58
	24.3	Successors and Assigns	58
	24.4	Waiver	58
	24.5	No Third Party Beneficiaries	58
	24.6	Rules of Construction	58
	24.7	Survival of Rights	59
	24.8	Rights and Remedies	59
	24.9	Interpretation	59
	24.10	Disclaimer of Agency	60
	24.11	No Sovereign Immunity	60
	24.12	Severance of Invalid Provisions	60
	24.13	Compliance with Laws	61
	24.14	Conflicts of Interest	61
	24.15	Expenses	61
	24.16	Scope	61
	24.17	Counterpart Execution	61
Annex I	Measurements and Tests of LNG at Receipt Point
Annex II	Measurements and Tests for Gas at Delivery Point
Exhibit A	Sabine Pass Services Manual
Exhibit B	Form of Port Liability Agreement

IV

LNG TERMINAL USE AGREEMENT

This LNG TERMINAL USE AGREEMENT (this “Agreement”), dated as of this [    ] day of [            ] (the “Effective Date”) is made by and between J&S Cheniere S.A., a company incorporated under the laws of Switzerland with an office at Route de Saint-Cergue 9, P.O. Box 1114, CH1260, Nyon-Switzerland (“Customer”); and Sabine Pass LNG, L.P., a Delaware limited partnership with a place of business at 717 Texas Avenue, Suite 3100, Houston, Texas, U.S.A. 77002 (“SABINE”).

RECITALS

WHEREAS, SABINE intends to construct, own and operate an LNG terminal facility near the mouth of the Sabine River in Cameron Parish, Louisiana capable of performing certain LNG terminalling services, including: the berthing of LNG vessels; the unloading, receiving and storing of LNG; the regasification of LNG; and the delivery of natural gas to the Delivery Point;

WHEREAS, Customer desires to purchase such LNG terminalling services from SABINE; and

WHEREAS, SABINE desires to make such LNG terminalling services available to Customer and to Other Customers in accordance with the terms hereof;

NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged by the Parties hereto and for the mutual covenants contained herein, SABINE and Customer hereby agree as follows:

PART ONE

PRINCIPAL COMMERCIAL TERMS AND CONDITIONS

The Parties hereby incorporate the General Terms and Conditions included as Part Two of this Agreement.

A. Term

Subject to the provisions of this Agreement, the term of this Agreement (“Term”) shall be equivalent to the unexpired term as set out in the Sales and Purchase Agreement.

B. Services Quantity

1. The “Maximum LNG Reception Quantity” shall be the quantity of LNG that Customer shall have the right to deliver to SABINE in any Contract Year which shall be equal to seventy eight million four hundred seventy five thousand (78,475,000) MMBTU per Contract Year. The quantity above shall be adjusted pursuant to Section 3.1(b)(i) for leap years and for the first and last Contract Years.

2. The “Maximum Gas Redelivery Rate” shall be equal to two hundred thousand 200,000 MMBTU per day.

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C. Fee and Retainage

The fees to be paid under this Agreement in accordance with Article 4 shall consist of the following:

1. A “Reservation Fee” payable per month equal to the product of:

a. twenty eight cents ($0.28) per MMBTU, and

b. the quotient of the Maximum LNG Reception Quantity divided by twelve (12).

a. An “Operating Fee” payable per month equal to the product of:

a. four cents ($0.04) per MMBTU, and

b. the quotient of the Maximum LNG Reception Quantity divided by twelve (12).

The Operating Fee shall be adjusted for inflation on January 1 of each Contract Year based on the increase in the United States Consumer Price Index (All Urban Consumers) from a basis set on January 1 of the year in which the Commercial Start Date occurs.

“Retainage” equal to two percent (2%) of the LNG delivered at the Receipt Point for Customer’s account. Included in such Retainage is fuel, including fuel for self-generated power and Gas unavoidably lost.

D. Notices

Pursuant to Article 23, the Parties have designated the following addresses for purposes of notices:

J&S Cheniere S.A. Route de Saint-Cergue P.O. Box 1114, CH1260 Nyon- Switzerland Attention: Fax: Telephone: Sabine Pass LNG, L.P. 717 Texas Avenue, Suite 3100 Houston, Texas 77002 Attention: President Fax: (713) 659-5459 Telephone: (713) 659-1361

E. Other Customers

Customer and SABINE acknowledge that TOTAL LNG USA, Inc. (“Total”) and Chevron U.S.A., Inc. (“Chevron”) are Other Customers of the Sabine Pass Facility. Customer and SABINE agree that Customer’s rights under this Agreement: (1) are subject to Total’s rights under that certain Terminal Use Agreement dated September 2, 2004, as amended, between Total and SABINE (“Total TUA”); and (2) are subject to Chevron’s rights under that certain Terminal Use Agreement dated November 8, 2004, as

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amended, between Chevron and SABINE (“Chevron TUA”). No provision of this Agreement shall be effective if and to the extent that it conflicts with a provision of an Existing Customer Agreement.

IN WITNESS WHEREOF, each of the Parties has caused this Agreement to be duly executed and signed by its duly authorized officer as of the Effective Date.

Sabine Pass LNG, L.P.
By:	Sabine Pass LNG-GP, Inc., its General Partner
By:
Name:	Keith G. Little
Title:	Attorney-in-Fact
J&S Cheniere S.A.
By:
Name:
Title:

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PART TWO

GENERAL TERMS AND CONDITIONS

ARTICLE 1

DEFINITIONS

In addition to any terms or expressions defined elsewhere in this Agreement, the terms or expressions set forth below shall have the following meanings in this Agreement:

1.1 “AAA” shall have the meaning set forth in Section 20.1(b)

1.2 “Adverse Weather Conditions” means weather and sea conditions actually experienced at or near the Sabine Pass Facility that are sufficiently severe either: (a) to prevent an LNG Vessel from proceeding to berth, or unloading or departing from berth, in accordance with one or more of the following: (i) regulations published by a Governmental Authority; (ii) an Approval; or (iii) an order of a Pilot; or (b) to cause an actual determination by the master of an LNG Vessel that it is unsafe for such vessel to berth, unload or depart from berth.

1.3 “Affiliate” means a Person (other than a Party) that directly or indirectly controls, is controlled by, or is under common control with, a Party to this Agreement, and for such purposes the terms “control”, “controlled by” and other derivatives shall mean the direct or indirect ownership of fifty percent (50%) or more of the voting rights in a Person.

1.4 “Aggregate Contracted Capacity” means, for each Contract Year, the sum of Customer’s Maximum LNG Reception Quantity and the maximum LNG reception quantity of the Other Customers in such Contract Year.

1.5 “Agreement” means this agreement (including Part One and Part Two hereof), together with the Annexes and Exhibits attached hereto, which are hereby incorporated into and made a part hereof, as the same may be hereafter amended.

1.6 “Allotted Unloading Time” shall have the meaning set forth in Section 8.7(a).

1.7 “Annual Delivery Program” shall have the meaning set forth in Section 5.1(f).

1.8 “Approvals” means all consents, authorizations, licenses, waivers, permits, approvals and other similar documents from or by a Governmental Authority.

1.9 “Available Unloading Date” means at any time an Unloading Date at one (1) of the two (2) berths that is not a Scheduled Unloading Date for Customer or one of the Other Customers at that berth.

1.10 “Base Rate” means: (a) the interest rate per annum equal to: (i) the prime rate (sometimes referred to as the base rate) for corporate loans as published by The Wall Street Journal in the money rates section on the applicable date; or (ii) in the event The Wall Street Journal ceases or fails to publish such a rate, the prime rate (or an equivalent thereof) in the United States for corporate loans determined as the average of the rates

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referred to as prime rate, base rate, or the equivalent thereof quoted by J.P. Morgan Chase & Co., or any successor thereof, for short term corporate loans in New York on the applicable date; plus (b) two percent (2%). The Base Rate shall change as and when the underlying components thereof change, without notice to any Person.

1.11 “British Thermal Unit” or “BTU” means the amount of heat required to raise the temperature of one (1) avoirdupois pound of pure water from fifty-nine (59) degrees Fahrenheit to sixty (60) degrees Fahrenheit at an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch.

1.12 “Business Day” means any day that is not a Saturday, Sunday or legal holiday in the State of Texas, or a day on which banking institutions chartered by the State of Texas, or the United States of America, are legally required or authorized to close.

1.13 “Cargo” means a quantity of LNG expressed in MMBTU carried by an LNG Vessel in relation to which SABINE will render Services to Customer hereunder.

1.14 “Central Time” means U.S. Central Time Zone, as adjusted for Daylight Saving Time and Standard Time.

1.15 “Claims” shall have the meaning set forth in Section 9.2(a) of this Agreement.

1.16 “Commercial Operations Completion” means completion of the Sabine Pass Phase 1 Facility so that the Sabine Pass Facility is ready to be used for its intended purpose to provide the Services hereunder, with the contractor under the engineering, procurement and construction contract for the facilities described in Section 7.1(b) having achieved all minimum acceptance requirements under such contract sufficient to provide the Services under this Agreement.

1.17 “Commercial Start Date” shall have the meaning set forth in Article 6.

1.18 “Consultation Notice” shall have the meaning set forth in Section 5.1(f).

1.19 “Contract Year” means each annual period starting on January 1 and ending on December 31 during the Term of this Agreement; provided, however, that: (a) the first Contract Year shall commence on the Commercial Start Date and end on the following December 31; and (b) the last Contract Year shall commence on January 1 immediately preceding the last day of the Term and end on the last day of the Term as set forth in Clause A.

1.20 “Cubic Foot” means a volume equal to the volume of a cube each edge of which is one (1) foot in length.

1.21 “Cubic Meter” means a volume equal to the volume of a cube each edge of which is one (1) meter in length.

1.22 “Customer” means the Party identified as the Customer in the preamble to this

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Agreement, unless and until substituted in whole by an assignee by novation in accordance with Section 17.3, whereupon such assignee shall become Customer to the extent of such assignment.

1.23 “Customer’s Inventory” means, at any given time, the quantity in MMBTU that represents LNG and Gas owed by SABINE for Customer’s account. Customer’s Inventory shall be determined after deduction of Retainage in accordance with Clause C.

1.24 “Customer’s LNG” means, for the purposes of the Services, LNG received at the Receipt Point for Customer’s account.

1.25 “Delivery Point” means the point of interconnect between the tailgate of the Sabine Pass Facility and a Downstream Pipeline.

1.26 “Dispute” means any dispute, controversy or claim (of any and every kind or type, whether based on contract, tort, statute, regulation, or otherwise) arising out of, relating to, or connected with this Agreement, including any dispute as to the construction, validity, interpretation, termination, enforceability or breach of this Agreement, as well as any dispute over the applicability of arbitration or jurisdiction.

1.27 “Downstream Pipeline” means all Gas pipelines with a connection at the Delivery Point which transport Gas from the Sabine Pass Facility.

1.28 “Effective Date” means the date set forth in the preamble of this Agreement.

1.29 “Estimated Time of Arrival” or its abbreviation “ETA” shall have the meaning set forth in Section 8.4(c)(i).

1.30 “Excess Services” shall have the meaning set forth in Section 3.1(c).

1.31 “Expected Receipt Quantity” means, with respect to a given Cargo, Customer’s reasonable estimate of the quantity of LNG (in MMBTU) expected to be unloaded at the Receipt Point, as set forth in the notice delivered pursuant to Sections 5.1(b)(ii) and 5.2(a), as such notice may be subsequently amended pursuant to Section 8.4(a).

1.32 “Extension Term” shall have the meaning set forth in Clause A.3.

1.33 “Fee” shall have the meaning set forth in Section 4.1.

1.34 “Force Majeure” shall have the meaning set forth in Section 15.1.

1.35 “for Customer”, “for Customer’s account”, “on behalf of Customer” or other phrases containing similar wording shall include LNG delivered to the Sabine Pass Facility at Customer’s direction as well as Customer’s Inventory derived therefrom.

1.36 “Governmental Authority” means, in respect of any country, any national, regional, state, or local government, any subdivision, agency, commission or authority thereof

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(including any maritime authorities, port authority or any quasi-governmental agency) having jurisdiction over a Party, the Sabine Pass Facility, Customer’s Inventory, an LNG Vessel, a Transporter, or a Downstream Pipeline, as the case may be, and acting within its legal authority.

1.37 “GPA” shall have the meaning set forth in Annex I.

1.38 “Gross Heating Value” means the quantity of heat expressed in BTUs produced by the complete combustion in air of one (1) Cubic Foot of anhydrous gas, at a temperature of sixty (60) degrees Fahrenheit and an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch, with the air at the same temperature and pressure as the gas, after cooling the products of the combustion to the initial temperature of the gas and air, and after condensation of the water formed by combustion.

1.39 “Henry Hub Price” shall mean, with respect to any month, the final settlement price in US$/ MMBTU as published by the New York Mercantile Exchange for the Henry Hub Natural Gas futures contract for Gas to be delivered during such month, such final price to be based upon the last trading day for the contract for such month; provided, however, that if the Henry Hub Natural Gas futures contract ceases to be traded, the Parties shall select a comparable index to be used in its place that maintains the intent and economic effect of the original index.

1.40 “Initial Term” shall have the meaning set forth in Clause A.2.

1.41 “International LNG Terminal Standards” means, to the extent not inconsistent with the express requirements of this Agreement, the international standards and practices applicable to the design, construction, equipment, operation or maintenance of LNG receiving and regasification terminals, established by the following (such standards to apply in the following order of priority): (a) a Governmental Authority having jurisdiction over SABINE; (b) the Society of International Gas Tanker and Terminal Operators (“SIGTTO”) to the extent adopted by SABINE; and (c) any other internationally recognized non-governmental agency or organization with whose standards and practices it is customary for Reasonable and Prudent Operators of LNG receiving and regasification terminals to comply.

1.42 “International LNG Vessel Standards” means, to the extent not inconsistent with the expressed requirements of this Agreement, the international standards and practices applicable to the ownership, design, equipment, operation, manning and maintenance of LNG vessels established by the following (such standards to apply in the following order of priority): (a) a Governmental Authority; (b) the International Maritime Organization; (c) SIGTTO; and (d) any other internationally recognized non-governmental agency or organization with whose standards and practices it is customary for Reasonable and Prudent Operators of LNG vessels to comply.

1.43 “Lender” means any entity providing temporary or permanent debt financing to SABINE in connection with construction or refinancing of the Sabine Pass Facility.

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1.44 “Liabilities” means all liabilities, costs, claims, disputes, demands, arbitrations, suits, legal or administrative proceedings, judgments, damages, losses and expenses (including reasonable attorneys’ fees and other reasonable costs of arbitration, litigation or defense), and any and all fines, penalties and assessments of, or responsibilities to, Governmental Authorities.

1.45 “Liquids” means liquid hydrocarbons capable of being extracted from LNG at the Sabine Pass Facility, consisting predominately of ethane, propane, butane and longer-chain hydrocarbons.

1.46 “Liquefied Natural Gas” or “LNG” means processed Natural Gas in a liquid state, at or below its boiling point at a pressure of approximately one (1) atmosphere.

1.47 “LNG Suppliers” means, in relation to performance of the obligations of SABINE and Customer under this Agreement, those Persons who agree in writing pursuant to an LNG purchase and sale agreement to supply or sell LNG to Customer for delivery to the Sabine Pass Facility.

1.48 “LNG Vessel” means an ocean-going vessel suitable for transporting LNG that Customer or an LNG Supplier uses for transportation of LNG to the Sabine Pass Facility.

1.49 “Loading Port” means the port at which a Cargo is loaded on board an LNG Vessel.

1.50 “Maximum Gas Redelivery Rate” shall have the meaning set forth in Clause B.

1.51 “Maximum LNG Reception Quantity” shall have the meaning set forth in Clause B.1.

1.52 “Measurement Dispute” shall have the meaning set forth in Section 20.2(a).

1.53 “MMBTU” means one million (1,000,000) BTU.

1.54 “Natural Gas” or “Gas” means any hydrocarbon or mixture of hydrocarbons consisting predominantly of methane which is in a gaseous state.

1.55 “New Regulatory Costs” shall have the meaning set forth in Section 4.2(a)(ii).

1.56 “Notice of Readiness” or “NOR” shall have the meaning set forth in Section 8.5.

1.57 “Off-Spec LNG” shall have the meaning set forth in Section 9.5(a).

1.58 “Operating Fee” shall have the meaning set forth in Section 4.2(a)(ii).

1.59 “Other Customers” means, from time to time, Persons (other than Customer) purchasing LNG terminalling services from SABINE similar to the Services, regardless of the short-term or long-term duration of such terminal use agreement.

1.60 “Party” and “Parties” means SABINE and Customer, and their respective successors and assigns.

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1.61 “Person” means any individual, sole proprietorship, corporation, trust, company, voluntary association, partnership, joint venture, limited liability company, unincorporated organization, institution, Governmental Authority or any other legal entity.

1.62 “Pilot” means any Person engaged by Transporter to come on board an LNG Vessel to assist the master in pilotage, berthing and unberthing of such LNG Vessel.

1.63 “Pilot Boarding Station” shall have the meaning set forth in Section 8.4(e).

1.64 “Port Charges” means all charges of whatsoever nature (including rates, tolls, dues of every description, and payments in lieu of taxes) in respect of an LNG Vessel entering or leaving the Sabine Pass Facility, including charges imposed by fire boats, tugs and escort vessels, the U.S. Coast Guard, a Pilot, and any other Person assisting an LNG Vessel to enter or leave the Sabine Pass Facility. Port Charges shall include port use fees, federal, state and local harbor maintenance taxes, throughput fees, and similar fees payable by users of the Sabine Pass Facility (or by SABINE on behalf of such users) to the local authorities.

1.65 “Proposed Unloading Date” means, for any applicable Contract Year, an unloading date proposed by Customer pursuant to Section 5.1.

1.66 “psig” means pounds per square inch gauge.

1.67 “Reasonable and Prudent Operator” means a Person seeking in good faith to perform its contractual obligations, and in so doing, and in the general conduct of its undertaking, exercising that degree of skill, diligence, prudence and foresight which would reasonably and ordinarily be expected from a skilled and experienced operator engaged in the same type of undertaking under the same or similar circumstances and conditions.

1.68 “Receipt Point” means the point at the Sabine Pass Facility at which the flange coupling of the Sabine Pass Facility’s receiving line joins the flange coupling of the LNG unloading manifold on board an LNG Vessel.

1.69 “Regasified LNG” means Gas derived from the conversion of LNG (received by SABINE at the Receipt Point) from its liquid state to a gaseous state.

1.70 “Reservation Fee” shall have the meaning set forth in Clause C.1.

1.71 “Retainage” shall have the meaning set forth in Clause C.

1.72 “Rules” shall have the meaning set forth in Section 20.1(a).

1.73 “SABINE” means Sabine Pass LNG, L.P. and its successors and assigns.

1.74 “Sabine Pass Expansion Commercial Operations Completion” means completion of the Sabine Pass Expansion Facilities so that the Sabine Pass Facility is ready to be used for its intended purpose to provide the Services hereunder, with the contractor under the

6

engineering, procurement and construction contract for the facilities described in Section 7.1(c) having achieved all minimum acceptance requirements under such contract sufficient to provide the Services under this Agreement.

1.75 “Sabine Pass Expansion Facilities” means the LNG receiving terminal facilities described in Section 7.1(c).

1.76 “Sabine Pass Facility” means the Sabine Pass Phase 1 Facilities and the Sabine Pass Expansion Facilities (including the port, berthing and unloading facilities, LNG storage facilities, and regasification facilities, together with equipment and facilities related thereto) necessary to provide Services hereunder, as such facilities will be constructed and modified from time to time in accordance with this Agreement.

1.77 “Sabine Pass Marine Operations Manual” shall have the meaning set forth in Section 8.2.

1.78 “Sabine Pass Phase 1 Facilities” means the LNG receiving terminal facilities described in Section 7.1(b).

1.79 “Sabine Pass Services Manual” shall have the meaning set forth in Section 3.5.

1.80 “Sabine Pass Website” means the internet based computer system used by SABINE to communicate with Customer and Other Customers regarding LNG terminalling services at the Sabine Pass Facility.

1.81 “SABINE Taxes” shall have the meaning set forth in Section 4.2(a)(i).

1.82 “Sales and Purchase Agreement” means the LNG sales and purchase agreement between J&S Cheniere S.A. and Cheniere LNG Marketing, Inc. dated [                , 2007].

1.83 “Scheduled Unloading Date” means, for any applicable Contract Year, an Unloading Date that is allocated either to Customer or any Other Customer pursuant to Section 5.1 or 5.2.

1.84 “Scheduling Representative” means the individual appointed by Customer in accordance with Section 5.5.

1.85 “Services” shall have the meaning set forth in Sections 2.1 and 3.1(b).

1.86 “Services Unavailability” shall have the meaning set forth in Section 4.3.

1.87 “Standard Cubic Foot” or “SCF” means the quantity of Natural Gas, free of water vapor, occupying a volume of one (1) Cubic Foot at a temperature of sixty (60) degrees Fahrenheit and at an absolute pressure of fourteen decimal six nine six (14.696) pounds per square inch.

1.88 “Taxes” means all customs, taxes, royalties, excises, fees, duties, levies, sales and use

7

taxes, ad valorem taxes, property taxes and value added taxes, charges and all other assessments, including payments in lieu of taxes, which may now or hereafter be enacted, levied or imposed, directly or indirectly, by a Governmental Authority, except Port Charges and taxes based on income, revenues, gross receipts or net worth and all state and local franchise, license, occupation and similar taxes required for the maintenance of corporate existence or to maintain good standing that are assessed against a Party.

1.89 “Term” shall have the meaning set forth in Clause A.

1.90 “Transporter” means any Person who owns or operates an LNG Vessel.

1.91 “Tribunal” shall have the meaning set forth in Section 20.1(c).

1.92 “Unloading Date” means a twenty-four (24) hour window starting at 6:00 a.m., Central Time on a specified day and ending twenty-four (24) consecutive hours thereafter.

1.93 “Unloading Date Change Request” shall have the meaning set forth in Section 5.2(c).

1.94 “Vacated LNG” shall have the meaning set forth in Section 9.1(c).

ARTICLE 2

SERVICES AND SCOPE

2.1 Services to be Provided by SABINE

During the Term and subject to the provisions of this Agreement, SABINE shall make available the following services to Customer (such available services being herein referred to as the “Services”) in the manner set forth herein:

(a) reasonable access to a berth for LNG Vessels at the Sabine Pass Facility;

(b) the unloading and receipt of LNG from LNG Vessels at the Receipt Point;

(c) the storage of Customer’s Inventory;

(d) the regasifying of LNG;

(e) the transportation and delivery of such Regasified LNG to the Delivery Point (it being acknowledged that SABINE may, at its option, cause Gas to be redelivered to Customer at the Delivery Point from sources other than Regasified LNG); and

(f) other activities directly related to performance by SABINE of the foregoing, including metering, custody transfer and reporting.

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2.2 Additional Services

From time to time during the Term, the representatives of SABINE and Customer may supplement this Agreement in accordance with Section 24.1 to provide that SABINE will also make available services to Customer in addition to the Services set forth in Section 2.1.

2.3 Activities Outside Scope of this Agreement

The Parties confirm that the following activities, inter alia, are not Services provided by SABINE to Customer and, therefore, such activities are outside of the scope of this Agreement:

(a) harbor, mooring and escort services, including those relating to tugs, service boats, line boats, fire boats, and other escort vessels;

(b) the construction, operation, ownership, maintenance, repair and removal of facilities downstream of the Delivery Point;

(c) the transportation of Gas beyond the Delivery Point;

(d) the marketing of Gas and all activities related thereto (except as expressly provided in Section 3.4); and

(e) the removal, marketing and transportation of Liquids and all activities related thereto. SABINE reserves the right to separate and/or extract Liquids from LNG upstream of the Delivery Point, provided that such separation does not result in Gas failing to meet the quality specifications at the Delivery Point required under Section 10.3 and provided, further, that SABINE delivers at the Delivery Point a quantity of Gas that is the thermal equivalent of the quantity of Gas nominated for delivery by Customer pursuant to Section 5.3(b). If Customer desires to have SABINE cause the Sabine Pass Facility to obtain the facilities necessary to reduce the Gross Heating Value of LNG and/or Gas (such capability being referred to as “BTU Control”), then Customer shall notify SABINE of such desire in writing, and the Parties shall discuss such matter in accordance with the following procedure:

(i) SABINE will investigate: (a) the construction of facilities to extract Liquids and/or inject nitrogen which are either an integral part of the Sabine Pass Facility or a separate project from the Sabine Pass Facility; and (b) the processing of Gas to extract Liquids and/or inject nitrogen in existing facilities in the area; and

(ii) if SABINE elects to construct facilities or make other processing arrangements to achieve BTU Control, the Parties shall discuss a commercially reasonable arrangement to compensate SABINE for such facilities or processing.

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ARTICLE 3

SALE AND PURCHASE OF SERVICES

3.1 Services

(a) Purchase and Sale of Services. During each Contract Year, SABINE shall make available to Customer, and Customer shall purchase and pay for in an amount equal to the Fee, the Services as described in Section 3.1(b).

(b) Services. The Services SABINE shall make available to Customer during each Contract Year, and which Customer shall purchase and pay for pursuant to Section 4.1, shall consist of the following:

(i) Unloading of LNG. SABINE shall make the Sabine Pass Facility available during a sufficient number of Unloading Dates during each Contract Year to permit the berthing, unloading and receipt as ratably as practical throughout such Contract Year of a quantity of Customer’s LNG equal to the Maximum LNG Reception Quantity; provided, however, that for purposes of the first and last Contract Years and any Contract Year that is a leap year, the Maximum LNG Reception Quantity shall be prorated based upon the ratio that the number of days during such Contract Year bears to three hundred sixty-five (365);

(ii) Storage of Customer’s Inventory. Customer’s LNG shall be stored temporarily and redelivered in accordance with Section 3.1(b)(iii) below; and

(iii) Redelivery of Gas. Each day during the Contract Year SABINE shall make Gas available to Customer at the Delivery Point at the rate nominated by Customer pursuant to Section 5.3(a).

(c) Excess Services. Separate and apart from the provisions of Section 3.1(b), SABINE may, in its sole discretion, allow berthing, unloading and receipt of quantities of LNG in excess of the Maximum LNG Reception Quantity, or redelivery of Gas at a rate different from that specified in Section 5.3(a) (collectively, “Excess Services”) in response to a request from Customer for such Excess Services. The fees applicable to such Excess Services shall be negotiated by the Parties.

3.2 Customer’s Use of Services

(a) Use Generally. Customer shall be entitled to use the Services in whole or in part by itself, or Customer may assign its rights and obligations as provided in Article 17.

(b) Expiration of Services. Notwithstanding any other term or condition of this Agreement, Customer’s failure or inability: (i) in any Contract Year to deliver Customer’s Maximum LNG Reception Quantity to SABINE; or (ii) on any day to

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take Gas for redelivery at the Delivery Point at the rate nominated in accordance with Section 5.3(a), including any portion of the Services not used in connection with a Partial Assignment, shall not serve to increase or decrease the Services to which Customer is entitled under Section 3.1(b) in any subsequent time period.

3.3 No Pre-Delivery Right

On any given day during a Contract Year, Customer shall not be entitled to receive quantities of Gas in excess of Customer’s Inventory.

3.4 Failure to Take Delivery of Gas at Delivery Point

If on any day Customer fails to: (a) nominate the quantity of Gas required by Section 5.3(b) to be redelivered for its account at the Delivery Point on the following day; or (b) fails materially to take redelivery at the Delivery Point of Gas at the rate nominated in accordance with Section 5.3(b) for its account on such day, and such failure is for reasons other than an event of Force Majeure or the inability of a Downstream Pipeline to take delivery of Customer’s Gas, such inability being not reasonably within the control of Customer, then SABINE may, at its sole discretion, take title to the quantity of Gas not nominated or taken on such day, free and clear of any Claims, and sell or otherwise dispose of such Gas using good faith efforts to obtain commercially reasonable prices and to minimize costs. Customer shall indemnify, defend and hold harmless SABINE, its Affiliates, and their respective directors, officers, members and employees, for the actual and reasonable costs incurred by SABINE as a result of such sale or other disposition of same by SABINE. SABINE shall credit to Customer’s account the net proceeds from the sale or other disposition of Gas from Customer’s Inventory to which it takes title hereunder, minus actual transportation costs, any other third party charges and an administrative fee of five U.S. cents ($0.05) per MMBTU; provided, however, that if the amount of the credit exceeds the amount due to SABINE under the next monthly statement, then SABINE agrees to pay any such excess amount to Customer within five (5) Business Days after delivery of such monthly statement. In the event SABINE is required to dispose of Customer’s Gas more than three (3) times in any Contract Year, the administrative fee shall be increased to ten U.S. cents ($0.10) per MMBTU for each occasion thereafter in such Contract Year.

3.5 Sabine Pass Services Manual

Acting as a Reasonable and Prudent Operator, SABINE shall develop and maintain a single services manual (the “Sabine Pass Services Manual”), applicable to Customer and all Other Customers, which shall take into consideration International LNG Terminal Standards, and which shall contain detailed implementation procedures consistent with the terms and provisions of this Agreement necessary for performance of this Agreement with regard to the matters set forth in Exhibit A attached hereto (but excluding the matters governed by the Sabine Pass Marine Operations Manual). SABINE shall deliver to Customer and all Other Customers a copy of the Sabine Pass Services Manual and any amendments thereto promptly after they have been finalized or amended, as the case may be. Customer shall comply and cause its Scheduling Representative to comply with such Sabine Pass Services Manual in all respects. SABINE will undertake to develop a

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Services Manual that is consistent with this Agreement; however, in the event of a conflict between the terms of this Agreement and the Sabine Pass Services Manual, the terms of this Agreement shall control.

ARTICLE 4

COMPENSATION FOR SERVICES

4.1 Fee

Commencing with the Commercial Start Date, each month Customer shall, as full compensation for the performance by SABINE of its obligations under this Agreement, bear the Retainage and in addition pay to SABINE the sum of the following three (3) components (such sum collectively referred to as the “Fee”).

(a) the Reservation Fee paid monthly in advance (prorated for any partial month);

(b) the Operating Fee paid monthly in advance (prorated for any partial month); and

(c) any additional charges to be paid by Customer under Section 4.2 herein.

4.2 Taxes and New Regulatory Costs

(a) If any Governmental Authority:

(i) imposes any Taxes on SABINE (excluding any Taxes on the capital revenue or income derived by SABINE) with respect to the Services, or on the Sabine Pass Facility (“SABINE Taxes”); or

(ii) subsequent to November 8, 2004, has enacted or does enact any safety or security related regulations which increases the costs of SABINE in relation to the Services or the Sabine Pass Facility (“New Regulatory Costs”);

then, Customer shall bear such SABINE Taxes and New Regulatory Costs proportionately with Other Customers with Customer’s share being determined for the given Contract Year based on the following ratio:

(x) Maximum LNG Reception Quantity; divided by

(y) Aggregate Contracted Capacity.

For the purposes hereof, SABINE Taxes shall not be reduced due to any inability to obtain, or the loss or expiration of, any abatement of SABINE Taxes; shall include any early payment of SABINE Taxes; and shall exclude any Taxes paid by Customer pursuant to Section 4.2(b).

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(b) If any Governmental Authority imposes a sales or use tax on Customer’s Retainage or any Tax or fee on the Services provided by SABINE to Customer, such tax shall be paid by Customer or reimbursed to SABINE by Customer if assessed on and paid by SABINE.

4.3 Services Unavailability

If some or all of the Services are unavailable to Customer on any day (or portion of a day) during the Term as a result of: (a) Force Majeure; or (b) an unscheduled curtailment or temporary discontinuation of Services pursuant to Section 16.2 (collectively a “Services Unavailability”), the Parties agree that the Fee shall not be adjusted. SABINE shall, to the extent operationally feasible and not disproportionately detrimental to Other Customers, use its reasonable efforts to restore Customer’s Services and allow Customer the ability to make-up any Services that have been lost as a result of the interruption of Services to the Sabine Pass Facility for no additional compensation.

4.4 Services Provided to Other Customers

Customer acknowledges that: (i) the compensation paid by Customer from time to time for Services may be less than, or more than, the price paid by Other Customers for the same or similar LNG terminalling services; and (ii) SABINE makes no representations or warranties to Customer in this regard.

ARTICLE 5

SCHEDULING

5.1 Annual Delivery Program

Procedures for the receipt of LNG at the Receipt Point and redelivery of Gas at the Delivery Point will be detailed in the Sabine Pass Services Manual, as modified from time to time, but generally in accordance with the following:

(a) SABINE Deliverables. Not later than one hundred and twenty (120) days prior to the beginning of each Contract Year, SABINE shall provide to the Scheduling Representative a non-binding written assessment of the dates of any planned maintenance to or modifications of the Sabine Pass Facility for such Contract Year and the expected impact of such activities on the availability of Services. SABINE shall use reasonable endeavors to limit the number of days of any planned maintenance to or modifications of the Sabine Pass Facility.

(b) Notice from Scheduling Representative. Not later than one hundred and five (105) days prior to the beginning of each Contract Year, the Scheduling Representative shall provide SABINE with the following:

(i) a programming schedule for the unloading of up to the Maximum LNG Reception Quantity over the course of the next Contract Year, which schedule shall specify, for each Cargo to be delivered to the Receipt Point, the proposed unloading date (the “Proposed Unloading Date”) of the applicable LNG Vessel and which schedule must result in a delivery pattern whereby: (a) deliveries in any given month do not materially exceed one twelfth (1/12) of the Maximum LNG Reception Quantity; (b) deliveries in any given month are generally ratable over the month; (c) deliveries take into consideration the planned maintenance and modification dates furnished to Customer by SABINE as set forth in Section 5.1(a); and (d) deliveries shall not be scheduled so as to utilize both unloading berths simultaneously; and

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(ii) for each Proposed Unloading Date proposed pursuant to Section 5.1(b)(i), the name of the LNG Vessel expected to deliver LNG to the Sabine Pass Facility (if the identity of the LNG Vessel is known to Customer at such time), the Expected Receipt Quantity, and the anticipated Gross Heating Value of the LNG to be delivered.

(c) Notices from Other Customers. Customer acknowledges that Other Customers will submit similar notices to SABINE regarding the matters provided for in Section 5.1(b).

(d) Customer Preliminary Receipt Schedule. SABINE shall take into consideration the notices that it receives from the Scheduling Representative and the Other Customers and, not later than ninety (90) days prior to the beginning of each Contract Year, SABINE shall issue to Customer via the Sabine Pass Website (or via an alternative electronic means of transmitting written communications if the Sabine Pass Website is unavailable) a preliminary receipt schedule for such Contract Year (the “Customer Preliminary Receipt Schedule”) showing a “Scheduled Unloading Date” for the LNG Vessel carrying each of Customer’s scheduled Cargoes, which schedule must result in a delivery pattern in which: (i) deliveries in any given month do not materially exceed one twelfth (1/12) of the Maximum LNG Reception Quantity; (ii) deliveries in any given month are generally ratable over the month; (iii) SABINE’s planned maintenance and modification dates are reflected; and (iv) deliveries are not scheduled so as to utilize both unloading berths simultaneously. Customer may propose to SABINE to change any such Scheduled Unloading Date, and SABINE agrees to give due consideration to, and use reasonable efforts to accommodate, such change.

(e) Other Customers’ Preliminary Receipt Schedules and Mutual Cooperation. Customer acknowledges that SABINE will issue to each Other Customer via the Sabine Pass Website (or alternative electronic means) a preliminary receipt schedule similar to the Customer Preliminary Receipt Schedule described in Section 5.1(d), but customized for each such Other Customer (“Other Customers’ Preliminary Receipt Schedules”). Customer also acknowledges that conflicts will occur in the preparation of the Customer Preliminary Receipt

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Schedule and Other Customers’ Preliminary Receipt Schedules because of the joint use of the Sabine Pass Facility among Customer and Other Customers. Accordingly, Customer agrees to cooperate with SABINE to assist SABINE in resolving any such conflict to the extent such cooperation does not result in material additional costs to Customer or unduly adversely impact the Services provided to Customer hereunder.

(f) Consultation; Annual Delivery Program. If the Scheduling Representative desires to consult with SABINE regarding the contents of the Customer Preliminary Receipt Schedule, the Scheduling Representative shall, no later than fifteen (15) days from the issuance of the Customer Preliminary Receipt Schedule, request to meet with SABINE by providing notice thereof (the “Consultation Notice”) to SABINE, and SABINE shall, no later than fifteen (15) days after receipt of the Consultation Notice, meet with the Scheduling Representative to discuss the Customer Preliminary Receipt Schedule. If: (i) the Scheduling Representative does not submit a Consultation Notice to SABINE on a timely basis; or (ii) the Scheduling Representative and SABINE meet pursuant to a Consultation Notice and are able during such meeting to agree upon revisions to the Customer Preliminary Receipt Schedule, then such Customer Preliminary Receipt Schedule, as so revised (and as updated from time to time for such Contract Year in accordance with the provisions of this Agreement by SABINE via the Sabine Pass Website), together with the planned maintenance and modification dates selected by SABINE, shall constitute the “Annual Delivery Program”. If the Scheduling Representative and SABINE meet pursuant to a Consultation Notice and are unable during such meeting to agree upon revisions to the Customer Preliminary Receipt Schedule, then SABINE shall determine, while using its reasonable efforts to accommodate Customer’s views, the Annual Delivery Program. Such Annual Delivery Program shall, to the extent practicable, result in a delivery pattern in which: (i) deliveries in any given month do not materially exceed one twelfth (1/12) of the Maximum LNG Reception Quantity; (ii) deliveries in any given month are generally ratable over the month; (iii) SABINE’s planned maintenance and modification dates are reflected; and (iv) deliveries are not scheduled so as to utilize both unloading berths simultaneously. SABINE shall issue via the Sabine Pass Website (or via an alternative electronic means of transmitting written communications if the Sabine Pass Website is unavailable) the Annual Delivery Program no later than sixty (60) days prior to the first day of the Contract Year.

(g) Other Customers’ Annual Delivery Programs. Customer acknowledges that SABINE shall issue to each Other Customer a final receipt schedule similar to the Annual Delivery Program described in Section 5.1(f) but customized for each such Other Customer (such schedules referred to as “Other Customers’ Annual Delivery Programs”).

(h) Adjustment to Schedules. Upon written request by Customer, SABINE shall use reasonable efforts to modify the time periods expressly set forth in Sections 5.1(b) and 5.1(d) to allow Customer to interface these periods with corresponding time

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periods for scheduling agreed upon by Customer and its LNG Suppliers. For purposes of this Section 5.1, SABINE shall be deemed to have used reasonable efforts if SABINE rejects Customer’s request because it determines, acting as a Reasonable and Prudent Operator, that any such modification would infringe on the contractual rights of Other Customers.

(i) Available Unloading Dates. Throughout the Contract Year, SABINE shall maintain on the Sabine Pass Website (or via an alternative electronic means of transmitting written communications if the Sabine Pass Website is unavailable) a current list of Available Unloading Dates.

5.2 Three Month Schedules

(a) Proposed Schedules. Not later than the first (1st) day of each month in a Contract Year, Customer shall deliver the following to SABINE: a proposed three-month forward plan of delivery of LNG (“Proposed Three Month Unloading Schedule”), which follows the Annual Delivery Program as nearly as practicable and sets forth by voyages and the projected dates thereof the pattern of shipments forecast for each of the next three (3) months and the Expected Receipt Quantity of each such shipment.

(b) Three Month Unloading Schedules. Thereafter, and not later than the twentieth (20^th) day of each month in which a Proposed Three Month Unloading Schedule is delivered, SABINE shall deliver the following to Customer: a final three-month forward plan of delivery of LNG (“Three Month Unloading Schedule”), which shall supersede Customer’s Proposed Three Month Unloading Schedule and prior Three Month Unloading Schedules as well as the portion of the Annual Delivery Program covering the same time periods and which shall reflect to the extent operationally practicable Customer’s Proposed Three Month Unloading Schedule.

(c) Customer Changes to the Annual Delivery Program or Three Month Unloading Schedule. At any time following the issuance of the Annual Delivery Program and any applicable Three Month Unloading Schedule, Customer’s Scheduling Representative may submit to SABINE a written request to change a Scheduled Unloading Date to any Available Unloading Date (such request to change, a “Customer Unloading Date Change Request”). Customer understands that: (a) Other Customers shall also have the right to submit to SABINE similar scheduling requests (each an “Other Customer Unloading Date Change Request”); (b) SABINE shall have no obligation to consult with the Scheduling Representative, Customer, or Other Customers regarding any Customer Unloading Date Change Request or Other Customer Unloading Date Change Request (collectively, “Unloading Date Change Requests”); and (c) SABINE shall accept any Unloading Date Change Request on a first-come, first-served basis. Upon accepting a Customer Unloading Date Change Request, SABINE shall notify Customer via the Sabine Pass Website (or via an alternative electronic means of transmitting written communications if the Sabine Pass Website is unavailable) as soon as practical but not later than 5:00 p.m. Central Time of the

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day following the date of receipt by SABINE of the applicable Unloading Date Change Request. Notwithstanding anything herein to the contrary, Customer shall use its reasonable efforts to keep to a minimum the number of Customer Unloading Date Change Requests it submits to SABINE.

(d) Other Modifications to the Annual Deliver Program or Three Month Unloading Schedule. If Customer is unable to berth during its Scheduled Unloading Date due to a Force Majeure event (an “Unloading Services Unavailability”), each affected Scheduled Unloading Date allocated to Customer during such period shall be cancelled, to the extent affected; provided, however, that in the event of an Unloading Services Unavailability causing the cancellation of one or more Scheduled Unloading Dates allocated to Customer and/or Other Customers, SABINE shall make reasonable efforts to change the Three Month Unloading Schedule and Other Customers’ Annual Delivery Programs in order to maximize efficient usage of the Sabine Pass Facility to assist Customer and Other Customers to unload quantities of LNG which would otherwise have been unloaded at the Sabine Pass Facility during such cancelled Scheduled Unloading Dates.

5.3 Gas Delivery

(a) Preliminary Nomination Schedule. Not later than the fifteenth (15th) day of each month, commencing the month immediately prior to the Commercial Start Date, Scheduling Representative shall provide to SABINE a nonbinding nomination schedule (“Preliminary Nomination Schedule”) that sets forth, for each day of the succeeding month, the quantities of Gas Customer expects to nominate for redelivery for its account at the Delivery Point.

(b) Daily Nomination Schedule. Each day by no later than 9:00 a.m. Central Time Customer shall notify SABINE of its actual nomination of the quantities of Gas to be redelivered for its account at the Delivery Point on the following day in compliance with this Section 5.3(b) and Sections 5.3(c) and 5.3(d). SABINE shall be obligated to redeliver such quantities to Customer in accordance with its nomination. Any nomination submitted by Customer’s Scheduling Representative in accordance with the foregoing provision shall be ratable throughout the day and shall remain in effect until changed by it in accordance with such provision. Customer shall manage its nominations in a manner that will ensure that the projected Customer’s Inventory shall not exceed two hundred thousand (200,000) MMBTU at 9 a.m. Central Time on any day on which an LNG Vessel is projected by SABINE to be unloading.

(c) Maximum Gas Redelivery Rate. Except as modified pursuant to Section 5.3(e), Customer’s daily nomination shall not exceed the lesser of:

(i) the Maximum Gas Redelivery Rate; and

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(ii) the projected remaining quantity of Customer’s Inventory at 9:00 a.m. Central Time on that day.

(d) Minimum Gas Redelivery Rate. Customer’s daily nomination shall not be less than Customer’s commercially reasonable share of tank boil-off (“Minimum Gas Redelivery Rate”).

(e) Changes in Gas Redelivery Rates. To the extent, on any day, that SABINE has the ability to allow Customer to nominate a higher Gas redelivery rate than the Maximum Gas Redelivery Rate, SABINE may, at its sole option, advise Customer of the amount of such change that is available on such day and the fee associated with such change.

5.4 Standard

SABINE shall act as a Reasonable and Prudent Operator in performing the scheduling activities required by this Article 5.

5.5 Scheduling Representative

By no later than six (6) months prior to the Commercial Start Date, Customer shall appoint an individual to act as Scheduling Representative for the purposes of this Article 5; provided, however, that Customer shall have the right to change its appointed Scheduling Representative at any time by notice to SABINE. Unless otherwise stated herein, Customer hereby authorizes the Scheduling Representative to do and perform any and all acts for and on behalf of Customer with regard to scheduling matters provided for in this Article 5. SABINE acknowledges that Customer and any Other Customer may agree to coordinate their activities so as to make the most efficient use of the Sabine Pass Facility, and may for purposes of this Agreement and the terminal use agreements of the Other Customers jointly appoint a Scheduling Representative.

5.6 Scheduling Coordination Among Customer and Other Customers

Customer shall have the right to request SABINE to arrange a joint meeting with Other Customers with respect to any matter in relation to the performance of this Article 5. SABINE shall use reasonable efforts to organize such a meeting, provided that SABINE may elect to include additional Other Customers if SABINE determines that such matter affects such additional Other Customers. If the Other Customers invited by SABINE agree to participate in such a joint meeting among Customer, Other Customers and SABINE, the joint meeting shall be held as soon as practical. SABINE shall have the right to settle any scheduling disputes that may arise among Customer and Other Customers. Unless otherwise agreed, any such joint meeting shall be held in Houston, Texas or by telephone, as appropriate.

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ARTICLE 6

COMMERCIAL START DATE

The “Commercial Start Date” shall be the date on which Commercial Operations Completion occurs, regardless of whether any unloading of Customer’s LNG at the Sabine Pass Facility actually occurs on such date.

ARTICLE 7

SABINE PASS FACILITY

7.1 Sabine Pass Facility

(a) Standard of Operation. SABINE shall cause the Sabine Pass Facility to be constructed and commissioned so as to achieve Commercial Operations Completion. On and after the Commercial Start Date, SABINE shall at all times provide, maintain and operate (or cause to be provided, maintained and operated) the Sabine Pass Facility taking into consideration the following: (i) International LNG Terminal Standards; and (ii) to the extent not inconsistent with International LNG Terminal Standards, such good and prudent practices as are generally followed in the LNG industry by Reasonable and Prudent Operators of LNG receiving and regasification terminals.

(b) Sabine Pass Phase 1 Facilities to be Provided. Subject to Section 7.1(a), the Sabine Pass Phase 1 Facilities shall include the following:

(i) appropriate systems for communications with LNG Vessels;

(ii) two unloading berths, each capable of berthing an LNG Vessel having a displacement of no more than 166,600 tonnes, an overall length of no more than 1,140 feet, a beam of no more than 175 feet, and a draft of no more than 40 feet, which LNG Vessels can safely reach, fully laden, and safely depart, and at which LNG Vessels can lie safely berthed and unload safely afloat;

(iii) lighting sufficient to permit berthing, unberthing and unloading operations by day or by night, to the extent permitted by Governmental Authorities and Pilots (it being acknowledged, however, that SABINE shall in no event be obligated to allow nighttime berthing operations at the Sabine Pass Facility if SABINE determines, acting as a Reasonable and Prudent Operator, that such operations during nighttime hours could pose safety or operational risks to the Sabine Pass Facility, an LNG Vessel, or a third party);

(iv) unloading facilities capable of receiving LNG at a rate of up to an average of 12,000 Cubic Meters per hour when the pressure at the Receipt Point is at least 5.6 bars (gauge), with three (3) unloading arms each having a reasonable operating envelope to allow for ship movement and manifold strainers of sixty (60) mesh;

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(v) a vapor return line system of sufficient capacity to transfer to an LNG Vessel quantities of Gas necessary for the safe unloading of LNG at the required rates, pressures and temperatures;

(vi) facilities allowing ingress and egress between the Sabine Pass Facility and the LNG Vessel by: (a) representatives of Governmental Authorities for purposes of unloading operations; and (b) an independent surveyor for purposes of conducting tests and measurements of LNG on board the LNG Vessel in accordance with Annex I;

(vii) LNG storage facilities with a working capacity of approximately four hundred eighty thousand (480,000) Cubic Meters of LNG;

(viii) LNG regasification facilities with a total daily capacity of up to 2.6 billion Standard Cubic Feet; and

(ix) metering, piping and flange at the Delivery Point necessary for the purpose of connecting to the Downstream Pipeline.

(c) Sabine Pass Expansion Facilities to be Provided. Subject to Section 7.1(a), the Sabine Pass Expansion Facilities shall include at least the following:

(i) LNG storage facilities with a working capacity of approximately three hundred twenty thousand (320,000) Cubic Meters of LNG; and

(ii) LNG regasification facilities with a total daily capacity of approximately 1.4 billion Standard Cubic Feet.

(d) Facilities Not Provided. Services and facilities not provided at the Sabine Pass Facility include the following:

(i) facilities and loading lines for liquid or gaseous nitrogen to service an LNG Vessel;

(ii) facilities for providing bunkers; and

(iii) facilities for the handling and delivery to the LNG Vessel of ship’s stores, provisions and spare parts.

(e) Expansion. SABINE shall have the right, but not the obligation, from time to time, to expand the Sabine Pass Facility or to construct or acquire other facilities.

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7.2 Compatibility of Sabine Pass Facility with LNG Vessels

(a) Sabine Pass Facility General Specifications. SABINE has provided to Customer the general specifications for the LNG berthing and unloading facilities of the Sabine Pass Facility as of the date hereof.

(b) LNG Vessel Compatibility. Customer shall ensure, at no cost to SABINE, that each of the LNG Vessels is fully compatible with the Sabine Pass Facility as set forth in such general specifications. Should an LNG Vessel fail materially either to be compatible with the Sabine Pass Facility, or to be in compliance with the provisions of Article 8, Customer shall not employ such LNG Vessel until it has been modified to be so compatible or to so comply.

(c) Modifications to Terminal Generally. The Parties agree that, after the date hereof, SABINE shall be entitled to modify the Sabine Pass Facility in any manner whatsoever, provided that: (x) such modifications do not render the Sabine Pass Facility incompatible with an LNG Vessel that was previously compatible with the Sabine Pass Facility under Section 7.2(b) above; (y) such modifications, once finalized, do not reduce the ability of SABINE to provide the Services to Customer on the basis set forth in this Agreement; and (z) such modifications do not otherwise conflict with SABINE’s obligations under this Agreement. Notwithstanding the foregoing, SABINE may modify the Sabine Pass Facility in a manner that would render it incompatible with an LNG Vessel provided that:

(i) such modification is necessary for SABINE to comply with its obligations under Section 7.1(a); or

(ii) the LNG Vessel is capable of being modified, and such modification is minor in nature, to maintain compatibility with both the Sabine Pass Facility and other terminals in its normal/intended trade and, in connection with a modification, SABINE reimburses Customer for the reasonable actual costs incurred by Customer in causing Transporter to modify the LNG Vessel to maintain compatibility with the Sabine Pass Facility as so modified; provided, further, that Customer shall use its best efforts to minimize costs to be borne by SABINE hereunder, shall notify SABINE reasonably in advance of the nature and expected cost of all such LNG Vessel modifications by Transporter, and shall certify to SABINE the actual amount and detail of all costs incurred for which such reimbursement from SABINE is requested.

(d) Modifications to Terminal Resulting From Changes in International LNG Vessel Standards. In the event of a change in International LNG Vessel Standards which requires an LNG Vessel to be modified but such vessel modification would render such LNG Vessel incompatible with the Sabine Pass Facility, then SABINE shall use its best efforts to modify the Sabine Pass Facility to render it compatible with such modified LNG Vessel provided that:

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(i) such modifications do not render the Sabine Pass Facility incompatible with another LNG vessel that was previously compatible with the Sabine Pass Facility;

(ii) such modifications, once finalized, do not reduce the Services; and

(iii) such modifications do not otherwise conflict with SABINE’s obligations under this Agreement.

7.3 Customer Inspection Rights

Upon obtaining SABINE’s prior written consent, which consent shall not be unreasonably withheld or delayed, a reasonable number of Customer’s designated representatives (including LNG Suppliers) may from time to time (including during the period of initial construction) inspect the operation of the Sabine Pass Facility so long as such inspection occurs from 8:00 a.m. Central Time to 5:00 p.m. Central Time on a Business Day. Any such inspection shall be at Customer’s sole risk and expense. Customer (and its designees) shall carry out any such inspection without any interference with or hindrance to the safe and efficient operation of the Sabine Pass Facility. Customer’s right to inspect and examine the Sabine Pass Facility shall be limited to verifying SABINE’s compliance with SABINE’s obligations under this Agreement and shall not entitle Customer to make direct requests to SABINE regarding any aspect of the Sabine Pass Facility. No inspection (or lack thereof) of the Sabine Pass Facility by Customer hereunder, or any requests or observations made to SABINE or its representatives by or on behalf of Customer in connection with any such inspection, shall (a) modify or amend SABINE’s obligations, representations, warranties and covenants under this Agreement or under any agreement or instrument contemplated by this Agreement; or (b) constitute an acceptance or waiver by Customer of SABINE’s obligations under this Agreement.

ARTICLE 8

TRANSPORTATION AND UNLOADING

8.1 LNG Vessels

(a) Customer to Cause LNG Vessels to Comply. Customer shall be responsible for the transportation of LNG from the Loading Port to the Receipt Point. In this regard, Customer shall cause each LNG Vessel to comply with the requirements of this Article 8 in all respects.

(b) Approvals and Documentation. Each LNG Vessel shall comply with the regulations of, and obtain all Approvals required by, Governmental Authorities to enable such LNG Vessel to enter, leave and carry out all required operations at the Sabine Pass Facility. Each LNG Vessel shall at all times have on board valid documentation evidencing all such Approvals. Each LNG Vessel shall comply fully with the International Safety Management Code for the Safe Operation of Ships and Pollution Prevention effective July 1, 1998, and at all times be in possession of a valid safety management certificate.

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(c) Tugs, Fireboats and Escort Vessels. Customer shall arrange for, or cause the appropriate Person to arrange for, such number and types of tugs, fireboats and escort vessels as are required by Governmental Authorities to attend the LNG Vessel so as to permit safe and efficient movement of the LNG Vessel within the maritime safety areas located in the approaches to and from the Sabine Pass Facility. SABINE requires that Customer arrange for, or cause the appropriate Person to arrange for, a minimum of three (3) 5000-horsepower, greater than fifty (50) short tons bollard pull tug boats with fire-fighting capability. Customer shall pay all Port Charges directly to the appropriate Person.

(d) LNG Vessel Requirements. Each LNG Vessel must satisfy the following requirements:

(i) Specifications. Except as otherwise mutually agreed in writing by the Parties, each LNG Vessel shall be compatible with the specifications of the Sabine Pass Facility identified in Section 7.1(b). Notwithstanding the foregoing, in the event an LNG Vessel is compatible with the specifications set forth in Section 7.1(b) or otherwise acceptable to SABINE, but a Governmental Authority or Pilot prohibits or otherwise hinders the utilization of such LNG Vessel, Customer’s obligations under this Agreement shall not be excused or suspended by reason of Customer’s inability (pursuant to the foregoing) to use such a vessel as an LNG Vessel.

(ii) LNG Vessel Capacity. Except as otherwise agreed in writing by SABINE, each LNG Vessel shall have an LNG cargo containment capacity of no less than eighty seven thousand six hundred (87,600) Cubic Meters.

(iii) Condition of the LNG Vessel. Each LNG Vessel shall be, in accordance with International LNG Vessel Standards: (a) fitted in every way for the safe loading, unloading, handling and carrying of LNG in bulk at atmospheric pressure; and (b) tight, staunch, strong and otherwise seaworthy with cargo handling and storage systems (including instrumentation) necessary for the safe loading, unloading, handling, carrying and measuring of LNG in good order and condition. The location of the unloading manifold shall allow a safe margin for movement of the arms within the operating envelope.

(iv) Classification Society. Each LNG Vessel shall at all times be maintained in class with any of the following: American Bureau of Shipping, Lloyd’s Register for Shipping, Bureau Veritas, Germanischer Lloyd, NKK, Det Norske Veritas or any other classification society that is mutually agreeable to the Parties.

(v) Construction. Each LNG Vessel shall have been constructed to all applicable International LNG Vessel Standards (including the International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk).

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(vi) Operation and Maintenance. Each LNG Vessel shall comply with, and shall be fully equipped, supplied and maintained to comply with, all applicable International LNG Vessel Standards. Unless approved by SABINE in writing, which approval shall not be unreasonably withheld or delayed, an LNG Vessel shall be prohibited from engaging in any maintenance, repair or in-water surveys while berthed at the Sabine Pass Facility, other than minor housekeeping repairs that do not affect the operation of the LNG Vessel. Each LNG Vessel shall comply fully with the guidelines of any Governmental Authority of the United States, including the National Oceanographic and Atmospheric Administration (NOAA), in relation to actions to avoid strikes in U.S. waters with protected sea turtles and cetaceans (e.g., whales and other marine mammals) and with regard to the reporting of any strike by the LNG Vessel which causes injury to such protected species.

(vii) Crew. The officers and crew of each LNG Vessel shall have the ability, experience, licenses and training commensurate with the performance of their duties in accordance with internationally accepted standards as adopted on first-class LNG vessels and as required by Governmental Authorities and any labor organization having jurisdiction over the LNG Vessel or her crew. Without in any way limiting the foregoing, the master, chief engineer, all cargo engineers and all deck officers shall be fluent in written and oral English and shall maintain all records and provide all reports with respect to the LNG Vessel in English.

(viii) Communications. Each LNG Vessel shall have communication equipment complying with applicable regulations of Governmental Authorities and permitting such LNG Vessel to be in constant communication with the Sabine Pass Facility and with other vessels in the area (including fireboats, escort vessels and other vessels employed in port operations).

(ix) Pumping Time. Provided that the Sabine Pass Facility supplies a suitable vapor return line meeting the requirements of Section 7.1(b)(v), then:

a. an LNG Vessel with an LNG cargo containment capacity less than or equal to one hundred forty thousand (140,000) Cubic Meters shall be capable of unloading LNG in a maximum of fifteen (15) hours; and

b. an LNG Vessel with an LNG cargo containment capacity greater than one hundred forty thousand (140,000) Cubic Meters shall be capable of unloading LNG in the number of hours derived after applying the following formula:

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15 + x = maximum LNG unloading time (in hours)

where:

x = y/12,000 Cubic Meters; and

y = the LNG cargo containment capacity of the LNG Vessel in excess of 140,000 Cubic Meters.

Time for connecting, cooling, stripping and disconnecting, and cooling of liquid arms shall not be included in the computation of pumping time.

8.2 Sabine Pass Marine Operations Manual

Acting as a Reasonable and Prudent Operator, SABINE shall develop and maintain a single marine operations manual (the “Sabine Pass Marine Operations Manual”) that governs activities at the Sabine Pass Facility, applies to all LNG Vessels and vessels used by Other Customers and which shall take into consideration International LNG Vessel Standards (but excluding the matters governed by the Sabine Pass Services Manual). SABINE shall deliver to Customer and all Other Customers a copy of the Sabine Pass Marine Operations Manual and any amendments thereto promptly after they have been finalized or amended, as the case may be. Customer shall comply, and shall cause its Scheduling Representative to comply, with such Sabine Pass Marine Operations Manual in all respects.

8.3 LNG Vessel Inspections; Right to Reject LNG Vessel

(a) Inspections. During the Term, on prior reasonable notice to Customer, SABINE acting as a Reasonable and Prudent Operator may, at its sole risk, send its representatives (including an independent internationally recognized maritime consultant) to inspect during normal working hours any LNG Vessel as SABINE may consider necessary to ascertain whether the LNG Vessel complies with the provisions of this Agreement. SABINE shall bear the costs and expenses in connection with any inspection conducted hereunder. Any such inspection may include, as far as is practicable having regard to the LNG Vessel’s operational schedule, examination of the LNG Vessel’s hull, cargo and ballast tanks, machinery, boilers, auxiliaries and equipment; examination of the LNG Vessel’s deck and engine scrap/rough and fair copy/official log books; review of records of surveys by the LNG Vessel’s classification society and relevant Governmental Authorities; and review of the LNG Vessel’s operating procedures and performance of surveys, both in port and at sea. Any inspection carried out pursuant to this Section 8.3(a): (i) shall not interfere with, or hinder, any LNG Vessel’s safe and efficient construction or operation; and (ii) shall not entitle SABINE or any of its representatives to make any request or recommendation directly to Transporter except through Customer. No inspection (or lack thereof) of an LNG Vessel hereunder shall: (x) modify or amend Customer’s obligations, representations, warranties and covenants under this Agreement or under any agreement or instrument contemplated by this Agreement; or (y) constitute an acceptance or waiver by SABINE of Customer’s obligations under this Agreement.

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(b) Right to Reject LNG Vessel. SABINE shall have the right to reject any LNG Vessel that Customer intends to use to deliver LNG to the Sabine Pass Facility if such LNG Vessel does not comply materially with the provisions of this Agreement, provided that:

(i) neither the exercise nor the non-exercise of such right shall reduce the responsibility of Customer to SABINE in respect of such LNG Vessel and her operation, nor increase SABINE’s responsibilities to Customer or third parties for the same; and

(ii) Customer’s obligations under this Agreement shall not be excused or suspended by reason of Customer’s inability (pursuant to the foregoing) to use a vessel as an LNG Vessel.

8.4 Advance Notices Regarding LNG Vessel and Cargoes

(a) Change in Expected Receipt Quantity. If, subsequent to issuing the notice required under Section 5.1(b)(ii) and Section 5.2(a), Customer anticipates a change, by way of either increase or decrease, of more than five percent (5%) in the Expected Receipt Quantity for a particular Cargo, Customer shall promptly provide notice thereof to SABINE and include in such notice Customer’s new estimate of the Expected Receipt Quantity. SABINE shall use reasonable endeavors to accept any increase in the quantity but shall at all times have the right not to accept such new increased quantity if, in its reasonable discretion, such increased quantity would conflict with any Other Customer’s unloading schedule or entitlement to Services or exceed Customer’s Service entitlements at the Sabine Pass Facility.

(b) LNG Vessel Nomination. As soon as practicable but no later than five (5) days prior to the scheduled loading date for a Cargo (unless the Cargo is a diversion cargo, in which case the notification shall be as soon as practicable after such diversion), Customer shall notify SABINE of the information specified below:

(i) name of LNG Vessel and, in reasonable detail, the dimensions, specifications, operator, and owner of such LNG Vessel;

(ii) name of Loading Port;

(iii) expected departure date of LNG Vessel from Loading Port;

(iv) estimated arrival date at the Sabine Pass Facility; and

(v) any changes in the Expected Receipt Quantity since Customer’s prior notice.

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(c) LNG Vessel Movements. With respect to each Cargo of LNG to be delivered hereunder, Customer shall give, or cause the master of the LNG Vessel to give, to SABINE the following notices:

(i) A first notice (“First Notice”), which shall be sent upon the departure of the LNG Vessel from the Loading Port and which shall set forth the time and date that loading was completed, the volume (expressed in Cubic Meters) of LNG loaded on board the LNG Vessel, the estimated time of arrival of the LNG Vessel at the Pilot Boarding Station (“ETA”), and any operational deficiencies in the LNG Vessel that may affect its performance at the Sabine Pass Facility or berth;

(ii) A second notice (“Second Notice”), which shall be sent ninety-six (96) hours prior to the ETA set forth in the First Notice, stating the LNG Vessel’s then ETA. If, thereafter, such ETA changes by more than six (6) hours, Customer shall give promptly, or cause the master of the LNG Vessel to give promptly, to SABINE notice of the corrected ETA;

(iii) A third notice (“Third Notice”), which shall be sent twenty-four (24) hours prior to the ETA set forth in the Second Notice (as corrected), confirming or amending such ETA. If, thereafter, such ETA changes by more than three (3) hours, Customer shall give promptly, or cause the master of the LNG Vessel to give promptly, to SABINE notice of the corrected ETA;

(iv) A fourth notice (“Final Notice”), which shall be sent twelve (12) hours prior to the ETA set forth in the Third Notice (as corrected), confirming or amending such ETA. If, thereafter, such ETA changes by more than one (1) hour, Customer shall give promptly, or cause the master of the LNG Vessel to give promptly, to SABINE notice of the corrected ETA; and

(v) An NOR, which shall be given at the time prescribed in Section 8.5(a) below.

Provided, however, the above notice requirements shall be waived by SABINE to the extent Customer is unable to practically provide the applicable notice as a result of Customer choosing to deliver recently acquired spot LNG Cargoes.

(d) Characteristics of Cargoes. With the First Notice, Customer shall notify SABINE, or cause SABINE to be notified, for SABINE’s information only, of the following characteristics of the LNG comprising its Cargo as determined at the time of loading:

(i) Gross Heating Value per unit;

(ii) molecular percentage of individual hydrocarbon components and nitrogen;

(iii) average temperature; and

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(iv) density at loading.

8.5 Notice of Readiness

(a) Issuance. Subject to any applicable restrictions, including any nighttime transit restrictions imposed by Governmental Authorities or Pilots or any other reasonable timing restrictions imposed by SABINE, the master of an LNG Vessel or its agent shall give to SABINE its notice of readiness (“NOR”), to unload upon arrival of such LNG Vessel at the specific location off the Sabine Pass Facility at which Pilots customarily board the LNG Vessel (such location referred to as the “Pilot Boarding Station”).

(b) Effectiveness. An NOR given under Section 8.5(a) shall become effective as follows:

(i) For an LNG Vessel arriving at the Pilot Boarding Station at any time before 6:00 a.m. Central Time on the Scheduled Unloading Date allocated to such LNG Vessel, an NOR shall be deemed effective at 6:00 a.m. Central Time on such Scheduled Unloading Date;

(ii) For an LNG Vessel arriving at the Pilot Boarding Station at any time between the period of 6:00 a.m. Central Time on the Scheduled Unloading Date allocated to such LNG Vessel and 6:00 a.m. Central Time on the day immediately following such Scheduled Unloading Date, an NOR shall become effective at the time of its issuance; or

(iii) For an LNG Vessel arriving at the Pilot Boarding Station at any time after the expiration of the Scheduled Unloading Date, an NOR shall become effective upon SABINE’s notice to the LNG Vessel that it is ready to receive the LNG Vessel at berth.

8.6 Berthing Assignment

(a) General Rule. SABINE shall determine the berthing sequence of all LNG Vessels at the Sabine Pass Facility in order to ensure compliance with the Annual Delivery Program and Three Month Unloading Schedules. If an LNG Vessel is not ready to unload for any reason, SABINE may refuse to allow it to berth.

(b) Timely Arrival. SABINE shall berth an LNG Vessel arriving before or during its Scheduled Unloading Date at the first opportunity that SABINE determines such LNG Vessel will not interfere with the berthing and unloading of any other scheduled LNG vessel with a higher berthing priority. Berthing priority for LNG vessels arriving before or during their respective Scheduled Unloading Dates shall be determined as follows:

(i) The first berthing priority on any day shall be for LNG vessels with a Scheduled Unloading Date on such day. Priority within this group shall be given to the LNG vessel which has first given SABINE its NOR; and

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(ii) The second berthing priority on any day shall be for LNG vessels with a Scheduled Unloading Date on a future day. Priority within this group shall be given to the LNG vessel which has first given SABINE its NOR.

For the avoidance of doubt, SABINE will allow berthing and unloading of LNG vessels from the priority group in Section 8.6(b)(ii) above only if, in SABINE’s sole judgment, such berthing and unloading will not cause the Sabine Pass Facility to lack either berthing space or sufficient storage capacity to allow unloading of an LNG vessel from the priority group in Section 8.6(b)(i).

(c) Late Arrival. SABINE shall berth an LNG Vessel arriving after its Scheduled Unloading Date at the first opportunity that SABINE reasonably determines such LNG Vessel will not cause the Sabine Pass Facility to lack either berthing space or sufficient storage capacity to allow unloading of an LNG vessel from the priority group in Section 8.6(b)(i).

8.7 Unloading Time

(a) Allotted Unloading Time. The allotted unloading time for each LNG Vessel (“Allotted Unloading Time”) shall be thirty-six (36) hours, subject to extensions for:

(i) reasons attributable to Customer, a Pilot, a Governmental Authority, the LNG Vessel or its master, crew, owner or operator, tugs, line boats, service boats, fire boats or other escort vessels, or attributable to any other party whose performance is required for the transiting and berthing of the LNG Vessel and whose performance is outside the control of SABINE;

(ii) Force Majeure;

(iii) unscheduled curtailment or temporary discontinuation of operations at the Sabine Pass Facility in accordance with Section 16.2; provided that in the circumstances described in Section 16.2(a), the repairs giving rise to such curtailment or discontinuance are reasonably necessary for the delivery of Services to Customer or Other Customers or for reasons of safety;

(iv) occupancy of the berth by an LNG vessel that arrived at berth at the Sabine Pass Facility no later than 6:00 p.m. Central Time of the scheduled unloading window allocated to such LNG vessel, which shall result in an extension of no more than nine (9) hours;

(v) additional time to unload an LNG Vessel with an LNG cargo containment capacity greater than one hundred forty thousand (140,000) Cubic Meters, such increase over thirty-six (36) hours to be calculated in the same manner as increases over twenty-four (24) hours under Section 8.9(b)(i)b;

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(vi) failure of an LNG Vessel to send the Final Notice pursuant to Section 8.4(c)(iv) or, pursuant to Section 8.4(c)(ii), failure of an LNG Vessel to give an NOR within six (6) hours of the ETA given to SABINE in the Second Notice; and

(vii) night time transit restrictions.

For the avoidance of doubt, SABINE shall have the right to delay berthing of the LNG Vessel for any of the reasons set forth in (i) to (vii) above.

(b) Actual Unloading Time. The actual unloading time for each LNG Vessel (“Actual Time”) shall commence when the NOR is effective and shall end when the unloading and return lines of the LNG Vessel are disconnected from the Sabine Pass Facility’s unloading and return lines.

(c) Demurrage

In the event Actual Unloading Time exceeds Allotted Unloading Time (including any extension in accordance with Section 8.7(a) (“Demurrage Event”), SABINE shall pay to Customer as liquidated damages demurrage in United States dollars (which shall be prorated for a portion of a day) determined in accordance with the rate set out in the following table:

LNG Vessel Cargo Capacity	Demurrage Rate in $/day
Less than 120,000 Cubic Meters	$	45,000
120,000 Cubic Meters or greater up to, but not including, 160,000 Cubic Meters	$	55,000
160,000 Cubic Meters or greater up to, but not including, 200,000 Cubic Meters	$	65,000
200,000 Cubic Meters or greater	$	83,000

If a Demurrage Event occurs, Customer shall invoice SABINE for such demurrage within thirty (30) days pursuant to Section 11.2.

(d) Excess Boil-Off. If an LNG Vessel is delayed in berthing at the Sabine Pass Facility and/or commencement of unloading due to an event occurring at the Sabine Pass Facility and for a reason that would not result in an extension of Allotted Unloading Time under Section 8.7, and if, as a result thereof, the commencement of unloading is delayed beyond twenty-four (24) hours after the Notice of Readiness is effective; then, for each full hour by which commencement

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of unloading is delayed beyond such twenty-four (24) hour period, SABINE shall pay Customer as liquidated damages an amount, on account of excess boil-off, equal to the Henry Hub Price multiplied by the quantity in MMBTUs equal to 0.0052% of the Cargo. Customer shall invoice SABINE for such excess boil-off pursuant to Section 11.2. This provision shall not apply if the LNG Vessel has onboard reliquefaction capability for boil-off.

8.8 Unloading at the Sabine Pass Facility

(a) Efficiency. SABINE shall cooperate with Transporters (or their agents) and with the master of each LNG Vessel to facilitate the continuous and efficient delivery of LNG hereunder.

(b) Vapor Return Line. During unloading of each Cargo of LNG, SABINE shall return to the LNG Vessel Gas in such quantities as are necessary for the safe unloading of the LNG at such rates, pressures and temperatures as may be required by the design of the LNG Vessel, and such returned Gas shall not be deemed to be volume unloaded for Customer’s account.

8.9 LNG Vessel Not Ready for Unloading; Excess Berth Time

(a) Vessel Not Ready for Unloading. If any LNG Vessel, previously believed to be ready for unloading, is determined to be not ready after being berthed, SABINE may direct the LNG Vessel’s master to vacate the berth and proceed to anchorage, whether or not other LNG vessels are awaiting the berth, unless it appears reasonably certain to SABINE that such LNG Vessel can be made ready without disrupting the overall unloading schedule of the Sabine Pass Facility or operations of the Sabine Pass Facility. When an unready LNG Vessel at anchorage becomes ready for unloading, its master shall notify SABINE. Upon the reberthing of any LNG Vessel vacated pursuant to this Section 8.9(a), Customer shall be responsible for any actual costs incurred by SABINE acting as a Reasonable and Prudent Operator as a result of such LNG Vessel not being ready for unloading.

(b) Berth Limitations.

(i) An LNG Vessel shall complete unloading and vacate the berth as soon as possible but not later than the following allowed berth time:

a. twenty-four (24) hours after the LNG Vessel has been berthed, in the case of an LNG Vessel with an LNG cargo containment capacity less than or equal to one hundred forty thousand (140,000) Cubic Meters; or

b. in accordance with the following formula, in the case of an LNG Vessel with an LNG cargo containment capacity greater than one hundred forty thousand (140,000) Cubic Meters:

24 + x = allowed berth time (in hours)

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where:

x = y/12,000 Cubic Meters; and

y = the LNG cargo containment capacity of the LNG Vessel in excess of 140,000 Cubic Meters.

(ii) Notwithstanding the foregoing, the aforementioned time restrictions shall be extended for: (a) reasons attributable to SABINE; (b) reasons attributable to a Pilot or to a Governmental Authority; (c) Force Majeure; and (d) nighttime transit restrictions.

(iii) If an LNG Vessel fails to depart at the end of its allowed berth time, SABINE may direct the LNG Vessel to vacate the berth and proceed to sea at utmost dispatch.

(iv) If an LNG vessel fails to vacate the berth after receipt of SABINE’s notice to do so under this Section 8.9, Customer shall reimburse SABINE, as liquidated damages amounts SABINE becomes contractually obligated to pay as demurrage or excess boil-off to any Other Customer. Such amounts to be paid in United States Dollars (which shall be pro rated for a portion of a day) determined in accordance with the table set out in Section 8.7(c).

(v) In the event an LNG Vessel fails to vacate the berth pursuant to this Section 8.9 and Customer is not taking actions to cause it to vacate the berth, SABINE may effect such removal at the expense of the Customer.

ARTICLE 9

RECEIPT OF LNG

9.1 Title, Custody and Risk of Loss

(a) Title to Customer’s Inventory, Risk of Loss. Subject to Section 3.4, SABINE shall not assume title or risk of loss with respect to Customer’s Inventory even during periods when it is in the possession and control of SABINE. For the avoidance of doubt, title and risk of loss with respect to Retainage shall pass to SABINE at the Receipt Point.

(b) Possession and Control. Possession and control of Customer’s LNG shall pass from Customer to SABINE upon delivery of same at the Receipt Point. Possession and control of Customer’s Gas shall pass from SABINE to Customer upon delivery of same at the Delivery Point.

(c) Vacated LNG. Customer agrees that SABINE may from time to time vacate from storage any quantity of Customer’s LNG as deemed appropriate by SABINE in its sole discretion to achieve efficient operation of the Sabine Pass Facility (“Vacated LNG”). Customer hereby consents to the transfer by SABINE of title

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and risk of loss for any quantity of Vacated LNG to itself, an Affiliate, or any other party. Such transfers shall not affect the responsibility of SABINE to store or otherwise account for Customer’s Inventory, as provided in Section 3.1(b)(ii), and to make available a quantity of Gas expressed in MMBTU equivalent to that of the Vacated LNG in accordance with Customer’s nominations, as provide in Section 3.1(b)(iii).

9.2 No Encumbrance

(a) Customer’s Covenants. Customer agrees to fully defend, indemnify and hold SABINE and its Affiliates harmless against all Encumbrances and Liabilities relating to such Encumbrances (collectively, “Claims”) regarding Customer’s Inventory, including Claims brought by Other Customers, other than any Claims caused by SABINE’s acts or omissions. For purposes of this Section 9.2(a), the term “Encumbrance” shall include any mortgage, pledge, lien, charge, adverse claim, proprietary right, assignment by way of security, security interest, title retention, preferential right or trust arrangement or any other security agreement or arrangement having the effect of security.

(b) SABINE’s Covenants. SABINE covenants that it will deliver to Customer at the Delivery Point all Gas held for Customer’s account free from all Claims relating thereto caused by SABINE’s acts or omissions. SABINE agrees to fully defend, indemnify and hold Customer and its Affiliates harmless from and against all Claims regarding Customer’s Inventory caused by the acts or omissions of SABINE and Other Customers.

9.3 Receipt of LNG

The receipt of LNG from an LNG Vessel at the Receipt Point shall be carried out by use of pumps and other equipment on the LNG Vessel under such reasonable and customary conditions as are specified in the Sabine Pass Marine Operations Manual.

9.4 Quality and Measurement of Customer’s LNG

Customer’s LNG shall be measured and tested in accordance with Annex I. Customer shall ensure that all LNG delivered at the Receipt Point for Customer’s account shall conform to the following specifications:

(a) Gross Heating Value.

LNG when delivered by Customer to SABINE shall have, in a gaseous state, a Gross Heating Value of not less than 950 BTU per Standard Cubic Foot and not more than 1165 BTU per Standard Cubic Foot.

(b) Components.

(i) The LNG when delivered by Customer to SABINE shall, in a gaseous state, contain not less than eighty-four molecular percentage (84.0 MOL%) of methane (C₁) and, for the components and substances listed below, such LNG shall not contain more than the following:

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a. Nitrogen (N2), 1.5 MOL%;

b. Ethane (C2), 11 MOL%;

c. Propane (C3), 3.5 MOL%;

d. Butanes (C4) and heavier, 2 MOL%;

e. Pentanes (C5) and heavier, 0.09 MOL%;

f. Hydrogen sulfide (H2S), 0.25 grains per 100 Standard Cubic Feet; and

g. Total sulfur content, 1.35 grains per 100 Standard Cubic Feet.

(ii) The LNG when delivered by Customer to SABINE shall contain no water, active bacteria or bacterial agents (including sulfate reducing bacteria or acid producing bacteria) or other contaminants or extraneous material.

9.5 Off-Specification LNG

(a) Refusal of Off-Spec LNG. Without prejudice to any other rights and remedies of SABINE hereunder, SABINE may refuse to take delivery of all or part of any LNG not conforming to the quality specifications set forth in Section 9.4 (“Off-Spec LNG”).

(b) Notice. Customer shall provide notice to SABINE as soon as reasonably practicable of any existing or anticipated failure of the LNG available for delivery to SABINE hereunder to conform to the quality specifications set forth in Section 9.4, giving details of the nature and expected magnitude of the variance, the cause of the non-compliance and the probable duration thereof, including the Cargoes and Scheduled Unloading Dates to be affected thereby. If so notified, SABINE shall as soon as possible inform Customer whether it intends to reject any of such Off-Spec LNG. If SABINE is notified by Customer prior to the commencement of unloading of a Cargo at the Sabine Pass Facility that the LNG is Off-Spec LNG and the quantity is delivered to the Sabine Pass Facility, SABINE shall use reasonable endeavors to take delivery of any Cargoes which it would otherwise be entitled to reject; provided, however that SABINE shall be entitled to delay unloading of Off-Spec LNG for the period of time reasonably required for SABINE to determine whether it can take delivery of such Off-Spec LNG pursuant to this Section 9.5(b). Subject to SABINE first using its reasonable endeavors to take delivery of any Cargoes containing Off-Spec LNG, SABINE shall:

(i) notify Customer that SABINE will take delivery of some or all of the affected Cargoes, without prejudice to SABINE’s rights and remedies with respect to such Off-Spec LNG other than SABINE’s right to reject said Cargo; or

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(ii) reject all or any of the affected Cargoes.

(c) Customer’s Responsibility. If SABINE accepts delivery of a Cargo of Off-Spec LNG which it would otherwise be entitled to reject, Customer shall:

(i) bear the financial responsibility for all reasonable and actual incremental costs (other than capital costs) and Liabilities incurred by SABINE or any of SABINE’s Affiliates, in each case acting as a Reasonable and Prudent Operator, in connection with receiving and treating Off-Spec LNG by such means as are appropriate, including blending such Off-Spec LNG with lower calorific value Gas or injecting nitrogen if facilities to allow for such blending or injection presently exist at the Sabine Pass Facility; and

(ii) indemnify and hold harmless SABINE, its Affiliates and their respective directors, officers and employees from any and all Liabilities, including any of same attributable to claims of any Person and any Other Customers, which arise out of, are incident to, or result from the acceptance, handling, disposal or use of Off-Spec LNG.

(d) No Continuing Waiver. Acceptance of Off-Spec LNG shall not prevent SABINE from refusing future deliveries of Off-Spec LNG. No waiver by SABINE of any default by Customer of any of the specifications set forth in this Article 9 shall ever operate as a continuing waiver of such specification or as a waiver of any subsequent default, whether of a like or different character.

(e) Extended Delivery of Off-Spec LNG. If: (i) Customer notifies SABINE pursuant to Section 9.5(b) of an anticipated delivery of two (2) or more Cargoes of Off-Spec LNG; and (ii) the Parties agree for SABINE to incur incremental capital costs in order to accept delivery of such Cargoes, then Customer shall, in addition to its payment and indemnification obligations under Section 9.5(c), bear the financial responsibility for and directly fund, at SABINE’s election, all such incremental capital costs.

ARTICLE 10

REDELIVERY OF GAS

10.1 General

(a) Delivery Point. SABINE shall deliver to Customer at the Delivery Point the quantity of Gas nominated by Customer for any day pursuant to Section 5.3.

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(b) Commingled Stream. Customer acknowledges and agrees that Gas from Customer’s Inventory may be delivered by SABINE in a commingled stream, including Gas derived from LNG received by SABINE from Other Customers. Customer furthers acknowledges and agrees that Customer shall have no right to receive Gas of the same quality as Customer’s LNG. SABINE shall, however, deliver at the Delivery Point a quantity of Gas that is, less Retainage, equal (in MMBTU) to the quantity of LNG received by SABINE for Customer’s account at the Receipt Point, and which Gas shall satisfy the requirements set forth in Section 10.3.

(c) Odorization. SABINE will deliver Gas from Customer’s Inventory at the Delivery Point in its natural state without the addition of any odorizing agent, and SABINE shall not be obligated to add odorizing agents to any Gas unless required to do so by a Governmental Authority. SABINE does not assume any responsibility for Liabilities by reason of the fact that it has not odorized the Gas from Customer’s Inventory prior to its delivery to Customer, except to the extent such liabilities arise from a failure to comply with the requirements of a Governmental Authority.

10.2 Customer’s Responsibility

(a) Downstream Arrangements. Customer shall arrange for the transportation of Gas by Downstream Pipelines in order to meet its obligations to take redelivery of Gas in accordance with the provisions of Section 3.4 at the rates nominated by it pursuant to Section 5.3. In this regard, Customer shall be solely responsible for making all necessary arrangements with third parties at or downstream of the Delivery Point to enable SABINE to deliver Gas to Downstream Pipelines on a timely basis pursuant to the terms and conditions of this Agreement. Customer shall also be solely responsible for ensuring that all such arrangements are consistent with the terms and conditions of this Agreement and shall require all relevant third parties to confirm to SABINE all of Customer’s nominations and scheduling of deliveries of Gas, such confirmation to be by telephone, electronic transmission, or other means acceptable to SABINE and the Downstream Pipelines. Such third-party arrangements shall be timely communicated to, and coordinated with, SABINE, and SABINE shall have no liability whatsoever for any failure of any such third party to provide downstream arrangements. The rules, guidelines, and policies of a Downstream Pipeline transporting or purchasing any Gas for or from Customer at the Delivery Point (as may be changed from time to time by the Downstream Pipeline) shall set forth, among other things, the manner in which Gas from Customer’s Inventory is transported from the Delivery Point. Customer and SABINE recognize that the receipt and delivery on the Downstream Pipeline’s facilities of Gas shall be subject to the operational procedures of such Downstream Pipeline.

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(b) Imbalance Charges. Customer shall use its reasonable efforts to avoid imposition of any scheduling fees, imbalance charges, cash out costs or similar costs, fees or damages for imbalances (“Imbalance Charges”) imposed by any Downstream Pipeline. Customer shall indemnify and hold harmless SABINE, its Affiliates and their respective directors, officers and employees from all Liabilities arising out of, incident to or resulting from any Imbalance Charges directly resulting from Customer’s acts or omissions.

(c) Limitation. Customer shall ensure that its Gas transportation and sales arrangements are in compliance with all applicable laws and regulations.

10.3 Specifications and Measurement of Gas at the Delivery Point

Gas delivered to Customer at the Delivery Point shall be measured and tested in accordance with Annex II. SABINE shall ensure that all Gas delivered at the Delivery Point for Customer’s account shall conform to the following specifications:

(a) Gross Heating Value. Gas when delivered by SABINE to Customer shall have a Gross Heating Value of not less than 950 BTU per Standard Cubic Foot and not more than 1165 BTU per Standard Cubic Foot.

(b) Components

(i) Gas when delivered by SABINE to Customer shall contain not less than eighty-two molecular percentage (82 MOL%) of methane (C₁) and, for the components and substances listed below, such Gas shall not contain more than the following:

a. Nitrogen (N2), 3 MOL%;

b. Pentanes (C5) and heavier, 0.1 MOL%;

c. Hydrogen sulfide (H2S), 0.25 grains per 100 Standard Cubic Feet;

d. Total sulfur content, 5 grains per 100 Standard Cubic Feet;

e. Oxygen (O2), 10 parts per million;

f. Carbon dioxide (CO2), 2 MOL%; and

g. Water (H2O), 7 pounds per one million Standard Cubic Feet.

(ii) Gas when delivered by SABINE to Customer shall contain no active bacteria or bacterial agents (including sulfate reducing bacteria or acid producing bacteria) or other contaminants or extraneous material.

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(c) Gas Delivery Pressure. Gas from Customer’s Inventory shall be delivered to the Delivery Point at the pressure necessary for the Gas to enter the system of the appropriate Downstream Pipeline but no greater than the maximum lawful operating pressure of the Downstream Pipeline, provided, however, that such pressure shall not be required to be less than 1000 psig and shall not be required to be greater than 1440 psig and at a temperature of not less than 40° Fahrenheit.

10.4 Nonconforming Gas

(a) Right to Reject. Unless SABINE has accepted Off-Spec LNG from Customer pursuant to Section 9.5, Customer shall have the right to reject Gas that does not conform to the specifications set forth in Section 10.3 (“Nonconforming Gas”) if the failure of such Nonconforming Gas to satisfy such specifications would: (i) be grounds for an operator of a Downstream Pipeline or a Person under contract with Customer to purchase such Gas (“Downstream Purchaser”) to reject such Nonconforming Gas; or (ii) otherwise materially and adversely affect Customer, in Customer’s reasonable opinion.

(b) SABINE Indemnity. If Customer accepts delivery of Non-Conforming Gas which it would otherwise be entitled to reject, SABINE shall indemnify and hold harmless Customer, its Affiliates and their respective directors, officers and employees from any and all Liabilities, including any of same attributable to claims of any Person (including Other Customers, a Downstream Pipeline, and a Downstream Purchaser), which arise out of, are incident to, or result from the acceptance, handling, disposal or use of Non-Conforming Gas. If Customer accepts delivery of Non-Conforming Gas which it would otherwise be entitled to reject, SABINE shall bear the financial responsibility for all reasonable and actual incremental costs (other than capital costs) and Liabilities incurred by Customer or any of Customer’s Affiliates, in each case acting as a Reasonable and Prudent Operator, in connection with accepting delivery of Non-Conforming Gas.

ARTICLE 11

PAYMENT

11.1 Monthly Statements

Between the first (1^st) day of each month and the tenth (10^th) day of each month, commencing with the month prior to the Commercial Start Date, SABINE shall deliver to Customer a statement setting forth the following:

(a) the Reservation Fee for the following month;

(b) the Operating Fee for the following month; and

any charges under Section 4.2 and/or Section 8.9 for the prior month.

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11.2 Other Statements

If any other moneys are due from one Party to the other hereunder and if provision for the invoicing of that amount due is not made elsewhere in this Article 11, then the Party to whom such moneys are due shall furnish a statement therefore to the other Party, along with pertinent information showing the basis for the calculation thereof.

11.3 Adjustments, Audit

(a) General. If, within ninety (90) days of the issuance by SABINE of a statement, SABINE acquires information indicating the necessity of an adjustment to such statement rendered hereunder, then SABINE shall promptly serve on Customer a written notice setting forth that information. Unless otherwise provided herein, after obtaining that information, SABINE shall promptly prepare and serve on Customer an adjusted statement, showing the necessary payment, the calculation of the payment amount, and the Party from whom the payment is owed. In the event Customer issued a statement and subsequently acquires information indicating the necessity of an adjustment to such statement, Customer shall follow the same procedure in issuing an adjusted statement.

(b) Audit. Upon thirty (30) days written notice issued within six (6) months of the conclusion of any Contract Year, Customer shall have the right to cause an internationally recognized firm of accountants, appointed by Customer at Customer’s sole expense, to audit the books, records and accounts of SABINE that are directly relevant to the determination of SABINE Taxes and New Regulatory Costs, LNG receipts and Gas deliveries for such prior Contract Year, as provided in statements issued to Customer pursuant to this Article 11. Such audit shall be conducted at the head office of SABINE and shall be completed within the Contract Year in which Customer’s notice is sent to SABINE. If Customer obtains information indicating the necessity of an adjustment to any statement rendered hereunder, then within ninety (90) days following completion of the audit pertaining to the affected Contract Year, Customer shall promptly serve on SABINE a statement pursuant to Section 11.2 and written notice setting forth the information and basis for such statement. If Customer waives its right to conduct an audit, statements may be contested by Customer only if, within a period of ninety (90) days after the end of the Contract Year, Customer serves on SABINE notice questioning their correctness. If no such notice is served, statements shall be deemed correct and accepted by both Parties. Promptly after resolution of any Dispute as to a statement, the amount of any overpayment or underpayment (plus interest as provided in Section 11.4(c)) shall be paid by SABINE or Customer to the other, as the case may be.

(c) Records. SABINE shall keep all books and records relevant to such audit for a period of three (3) years following the end of the relevant Contract Year; provided that where SABINE is on notice of a Dispute, SABINE shall keep all such books, records, and other information until such Dispute has been finally resolved.

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11.4 Payment Due Dates

(a) Due Date for Payment of Monthly Statement. Each monthly statement submitted pursuant to Section 11.1 shall become due and payable on the later of: (i) ten (10) days after delivery by SABINE of such monthly statement; or (ii) the twenty-fifth (25^th) day of the month in which such monthly statement was received; provided that if such day is not a Business Day, it shall become due and payable on the next Business Day.

(b) Due Date for Payment of Other Statements. Each statement submitted pursuant to Section 11.2 shall become due and payable on the thirtieth (30^th) day after the date on which it is received; provided that if such payment due date is not a Business Day, the due date for such payment shall be extended to the next Business Day. For purposes of this Section 11.4(b), a facsimile copy of an invoice shall be deemed received by a Party on the next Business Day following the day on which it was sent.

(c) Interest. Except as provided in Section 11.4(d), if the full amount of any statement is not paid when due, the unpaid amount thereof shall bear interest at the Base Rate, compounded annually, from and including the day following the due date up to and including the date when payment is made.

(d) Recurring Late Payments. If three (3) monthly statements submitted pursuant to Section 11.1 in a Contract Year are not paid when due, then, in addition to the remedies provided in Section 11.6 any late payment thereafter shall bear a charge equal to two percent (2%) of the unpaid amount thereof in lieu of interest at the Base Rate as provided in Section 11.4(c).

11.5 Payment

Each Party shall pay, or cause to be paid, in United States dollars in immediately available funds, all amounts that become due and payable by such Party pursuant to any statement issued hereunder, to a bank account or accounts designated by and in accordance with instructions issued by the other Party. Each payment of any amount owing hereunder shall be in the full amount due without reduction or offset for any reason (except as expressly allowed under this Agreement), including Taxes, exchange charges, or bank transfer charges. Notwithstanding the preceding sentence, the paying Party shall not be responsible for a designated bank’s disbursement of amounts remitted to such bank, and a deposit in immediately available funds of the full amount of each statement with such bank shall constitute full discharge and satisfaction of the statement.

11.6 Nonpayment

The term “Cumulative Delinquency Amount” shall mean, with respect to a Party, the cumulative amount, expressed in United States dollars, that is owed by that Party to the other Party under this Agreement and is past due. Without prejudice to a Party’s right of offset, if a Party’s failure to pay when due an amount owing hereunder causes its Cumulative Delinquency Amount to exceed three (3) times the Reservation Fee, then the Party to which such amount is owed shall have the right, upon giving thirty (30) days

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written notice (such notice hereinafter referred to as the “Delinquency Notice”) to the owing Party, to suspend performance of its obligations under this Agreement until such amount, with interest in accordance with Section 11.4(c), has been paid in full; provided, however, that: (a) no such suspension of a Party’s obligations under this Section 11.6 shall excuse the owing Party from the performance of its obligations hereunder; and (b) in the event that SABINE suspends performance under this Section 11.6: (i) Customer shall continue to be liable for the Fee pursuant to Section 4.1; and (ii) SABINE may offer Customer’s unutilized Services to the Other Customers. If any such Cumulative Delinquency Amount has not been paid within sixty (60) days after the issuance of the Delinquency Notice, then the Party to whom such amount is owed shall have the right, upon not less than thirty (30) days notice to the other Party, to terminate this Agreement without the necessity of any further action, unless within that thirty (30) day period, the Party to which such amount is owed receives payments from or on behalf of the owing Party equal to the Cumulative Delinquency Amount. Any such termination shall be without prejudice to any other rights and remedies of the terminating Party arising hereunder or by law or otherwise, including the right of such Party to receive payment in respect of all obligations and claims that arose or accrued prior to such termination or by reason of such default by the owing Party.

11.7 Disputed Statements

In the event of disagreement concerning any statement, Customer or SABINE (as the case may be) shall make provisional payment of the total amount thereof and shall immediately notify the other Party of the reasons for such disagreement, except that in the case of an obvious error in computation, Customer or SABINE (as the case may be) shall pay the correct amount disregarding such error. Subject to Section 11.3(b), statements may be contested by Customer or SABINE (as the case may be) only if, within a period of ninety (90) days after a Party’s receipt thereof, Customer or SABINE (as the case may be) serves on the other Party notice questioning their correctness. If no such notice is served, statements shall be deemed correct and accepted by both Parties. Promptly after resolution of any Dispute as to a statement, the amount of any overpayment or underpayment (plus interest as provided in Section 11.4(c)) shall be paid by SABINE or Customer to the other, as the case may be.

11.8 Final Settlement

Within sixty (60) days after expiration of the Term, SABINE and Customer shall determine the amount of any final reconciliation payment. After the amount of the final settlement has been determined, SABINE shall send a statement to Customer, or Customer shall send a statement to SABINE, as the case may be, in United States dollars for amounts due under this Section 11.8, and SABINE or Customer, as the case may be, shall pay such final statement no later than twenty (20) days after the date of receipt thereof.

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ARTICLE 12

DUTIES, TAXES AND OTHER GOVERNMENTAL CHARGES

Notwithstanding Section 4.2, Customer shall be responsible for and pay, or cause to be paid, all Taxes that may be imposed or levied on Customer’s Inventory (including receipt or redelivery thereof) and the LNG Vessels including any sales and use taxes that may be imposed on the Services or on SABINE for providing the Services to Customer. Customer shall reimburse and hold harmless SABINE for any such Taxes that may be required by law to be remitted by SABINE and shall pay such additional amount (including Taxes and corresponding interest at the Base Rate) as is necessary to ensure receipt by SABINE of the full amounts otherwise due to it under this Agreement. Notwithstanding the foregoing, neither Party shall be responsible for Taxes on the capital, revenue or income derived by the other Party. If any Governmental Authority requires Customer or SABINE to remit Taxes for which the other Party is responsible, the Party responsible for such Taxes shall promptly reimburse the other Party for such Taxes. Any Party entitled to an exemption from any such Taxes or charges shall furnish the other Party any necessary documentation thereof.

ARTICLE 13

INSURANCE

13.1 SABINE’s Insurance

SABINE shall be responsible for obtaining and maintaining insurance for the Sabine Pass Facility to the extent required by applicable law; and additional insurance, as is reasonably necessary and available on reasonable commercial terms, against such other risks and at such levels as a Reasonable and Prudent Operator of a shared use LNG receiving and regasification terminal would obtain. SABINE shall obtain such insurance from a reputable insurer (or insurers) reasonably believed to have adequate financial reserves. SABINE shall exercise its best efforts to collect any amount due to SABINE under such insurance policies. Any insurance policy required pursuant to this Section 13.1 shall contain a standard waiver of subrogation endorsement. In the event of a casualty that destroys or materially impairs the Sabine Pass Facility, SABINE, upon consent of Lenders, shall be required to utilize such insurance proceeds to cause the facility to be rebuilt or repaired as quickly as commercially practicable. Upon request of Customer, SABINE shall provide to Customer satisfactory evidence that the insurance required pursuant to this Section 13.1 is in effect. In any event SABINE shall be required to obtain the following insurance coverages:

(a) Commercial General Liability Insurance / Marine Terminal Operator’s Liability Insurance;

(b) Workers’ Compensation / Employer’s Liability;

(c) All-Risk Property Insurance; and

(d) Wharfingers Liability Insurance.

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In addition, during construction of the Sabine Pass Facility, SABINE shall cause the contractor under the engineering, procurement and construction contract to carry an appropriate level of insurance, including Construction All-Risk Insurance.

13.2 Customer’s Insurance

(a) Loss of Product Insurance. Customer acknowledges that SABINE shall not at any time be responsible for securing or maintaining loss of product insurance covering the risk of loss of Customer’s Inventory and that Customer shall be responsible for insuring against such risk. If Customer elects to obtain loss of product insurance that insures the physical damage or loss of Customer’s Inventory, SABINE shall, upon request of Customer, provide Customer all documents and information reasonably necessary to enable Customer to obtain such loss of product insurance.

(b) LNG Vessel Insurance. Customer shall ensure that insurances are procured and maintained for each LNG Vessel in accordance with the following provisions. In all cases, such insurance shall establish insurance coverages consistent with insurances to the standards which a ship owner operating reputable LNG vessels, as a Reasonable and Prudent Operator, should observe in insuring LNG vessels of similar type, size, age and trade as such LNG Vessel. In this regard:

(i) Hull and Machinery Insurance shall be placed and maintained with reputable marine underwriters; and

(ii) Protection & Indemnity Insurance (“P&I Insurance”) shall be placed and maintained as an unlimited entry, if such entry is available, with, and subject to, and on the basis of, the rules of any of the reputable international P&I insurance associations experienced in providing P&I Insurance for LNG vessels.

(c) Evidence of Insurance. Prior to the commencement of deliveries to the Sabine Pass Facility and thereafter at least once each Contract Year, Customer shall furnish the following evidence of insurance to SABINE in relation to each LNG Vessel: cover notes, certificates of entry, the latest rules of the particular provider, and detailed written information concerning all required insurance policies. These policies shall provide SABINE with thirty (30) days prior written notice of any cancellation, material change or alteration in coverage. These policies shall also contain a waiver of subrogation clause and name SABINE as an additional insured. The receipt of such information shall not impose any obligation on SABINE.

13.3 Port Liability Agreement

Notwithstanding any other provision of this Agreement and any rights that a Transporter may have under applicable law, each of SABINE and Customer agree to the Port Liability Agreement set forth in Exhibit B in relation to Liabilities for incidents involving an LNG Vessel occurring at the Sabine Pass Facility. Customer shall cause Transporter

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to execute the Port Liability Agreement in the form set forth on Exhibit B prior to Transporter’s LNG Vessel’s arrival at the Sabine Pass Facility. In the event a Transporter fails to execute such Port Liability Agreement, Customer shall indemnify and hold SABINE harmless from any Liabilities incurred by SABINE arising from such failure.

ARTICLE 14

LIABILITIES

14.1 Limitation of Liability of SABINE

In no case shall the liability of SABINE to Customer arising out of, relating to, or connected with an Event under this Agreement exceed three (3) times the Reservation Fee; provided, however, that the foregoing limitation shall not apply to Liabilities caused by the Gross Negligence/Willful Misconduct of SABINE.

For purposes of this Section 14.1, an “Event” means any occurrence or series of occurrences having the same origin, and “Gross Negligence/Willful Misconduct” means any act or failure to act (whether sole, joint or concurrent) by SABINE which was intended to cause, or which was in reckless disregard of or wanton indifference to, harmful consequences SABINE knew, or should have known, such act or failure would have on the safety or property of another Person.

14.2 Consequential Loss or Damage

Notwithstanding any other provision of this Agreement to the contrary, no Party shall be liable to the other Party for or in respect of:

(a) any consequential loss or damage, including loss of profits or business interruption; or

(b) any special, incidental or punitive damages

suffered or incurred by the other Party or any Person resulting from breach of or failure to perform this Agreement or the breach of any representation or warranty hereunder, whether express or implied, and whether such damages are claimed under breach of warranty, breach of contract, tort, or other theory or cause of action at law or in equity, except to the extent such damages have been awarded to a third party and are subject to allocation between or among the parties to the Dispute. For purposes of this Agreement, any amounts payable by Customer to its Gas purchasers or Gas suppliers for replacement Gas or other similar Liabilities shall be deemed to be a consequential loss or damage.

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14.3 Parties’ Liability

Customer’s sole recourse and remedy under this Agreement for a breach hereof or a default hereunder shall be against SABINE and its assets. Except as otherwise provided herein, SABINE’s sole recourse and remedy under this Agreement shall be against Customer and its assets for a breach hereof or a default hereunder. In the event of a breach of this Agreement, the non-breaching Party shall exercise commercially reasonable efforts to mitigate its damages resulting therefrom.

ARTICLE 15

FORCE MAJEURE

15.1 Events of Force Majeure

Neither Party shall be liable to the other for any delay or failure in performance hereunder if and to the extent such delay or failure is a result of Force Majeure. Subject to the provisions of this Article 15, the term “Force Majeure” shall mean any cause not within the control of the Party claiming suspension, and which by the exercise of due diligence, such Party has been unable to prevent or overcome, including without limitation acts of God, the government, or a public enemy: strikes, lockout, or other industrial disturbances; wars, blockades or civil disturbances of any kind; epidemics, Adverse Weather Conditions, fires, explosions, arrests and restraints of governments or people; freezing of, breakage or accident to, or the necessity for making repairs or alterations to tanks, machinery or lines of pipe, and unplanned outages of the Sabine Pass Facility. Nothing in this Article 15 shall be construed to require a Party to observe a higher standard of conduct than that required of a Reasonable and Prudent Operator as a condition to claiming the existence of Force Majeure.

15.2 Limitation on Scope of Force Majeure for Customer

Notwithstanding Section 15.1 of this Agreement, no Force Majeure shall relieve, suspend, or otherwise excuse Customer from performing any obligation to indemnify, reimburse, hold harmless or otherwise pay SABINE under this Agreement, including the obligations set forth in Clause C, Sections 3.4, 4.1, 7.3, 8.9, 9.2, 9.5, 10.2 and Article 4, Article 11, Article 12 and Article 20.

15.3 Notice

A Force Majeure event shall take effect at the moment such an event or circumstance occurs. Upon the occurrence of a Force Majeure event that prevents, interferes with or delays the performance by SABINE or Customer, in whole or in part, of any of its obligations hereunder, the Party affected shall give notice thereof to the other Party describing such event and stating the obligations the performance of which are affected (either in the original or in supplemental notices) and stating, as applicable:

(a) the estimated period during which performance may be prevented, interfered with or delayed, including, to the extent known or ascertainable, the estimated extent of such reduction in performance;

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(b) the particulars of the program to be implemented to resume normal performance hereunder;

(c) the anticipated portion of the Services for a Contract Year that will not be made available or received, as the case may be, by reason of Force Majeure; and

(d) where Section 15.7 applies, the quantity of Services that SABINE reasonably expects to allocate to Customer.

Such notices shall thereafter be updated at least monthly during the period of such claimed Force Majeure specifying the actions being taken to remedy the circumstances causing such Force Majeure.

15.4 Measures

In order to resume normal performance of this Agreement within the shortest time practicable, the Party affected by the Force Majeure shall take all measures that are commercially reasonable under the circumstances, taking into account the consequences resulting from such event of Force Majeure. Prior to resumption of normal performance, the Parties shall continue to perform their obligations under this Agreement to the extent not excused by such event of Force Majeure.

15.5 No Extension of Term

The Term shall not be extended as a result of or by the duration of an event of Force Majeure.

15.6 Settlement of Industrial Disturbances

Settlement of strikes, lockouts, or other industrial disturbances shall be entirely within the discretion of the Party experiencing such situations, and nothing herein shall require such Party to settle industrial disputes by yielding to demands made on it when it considers such action inadvisable.

15.7 Allocation of Services

If, as a result of an event of Force Majeure, SABINE is unable to meet its contractual obligations to Customer and any Other Customers under LNG terminal use agreements, SABINE shall allocate the available capability of the Sabine Pass Facility to perform activities similar to the Services to Customer and Other Customers in a reasonable manner based on the ratio that the Maximum LNG Reception Quantity bears to the Aggregate Contracted Capacity for the remainder of such Contract Year.

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ARTICLE 16

CURTAILMENT OF SERVICES

OR TEMPORARY DISCONTINUATION OF SERVICES

16.1 Scheduled Curtailment or Temporary Discontinuation of Services

To the extent that SABINE has notified Customer under Section 5.1(a) in connection with the preparation of the Annual Delivery Program of maintenance to or modification of the Sabine Pass Facility, SABINE shall, in addition to the rights set forth in Section 16.2, have the right during any Contract Year to curtail or temporarily discontinue the Services, in whole or in part due to such maintenance or modification. During the period of such curtailment or temporary discontinuation of Services, SABINE shall, from time to time, use reasonable endeavors to update Customer on the expected progress towards completing the maintenance or modification, whichever applicable. For purposes of this Section 16.1, a curtailment of or temporary discontinuation of Services shall mean any curtailment or temporary discontinuation lasting no more than three (3) consecutive days. Notwithstanding the foregoing, SABINE agrees that, for purposes of this Section 16.1, neither a curtailment nor a temporary discontinuation of Services pursuant to this Section shall reduce SABINE’s obligations to provide Services for Customer’s LNG in a quantity up to the Maximum LNG Reception Quantity.

16.2 Unscheduled Curtailment or Temporary Discontinuation of Services

SABINE shall have the right to curtail or temporarily discontinue the Services, in whole or in part, at any time in order to: (a) repair the Sabine Pass Facility or (b) protect persons and property, including the Sabine Pass Facility, from harm or damage due to operational or safety conditions. SABINE shall use reasonable endeavors to provide Customer such notice of curtailment or temporary discontinuation as is reasonable under the circumstances, and such notice may be issued for a specific period of time or until further notice is given. If, as a result of any unscheduled curtailment or temporary discontinuation of Services pursuant to this Section 16.2, SABINE is unable to meet its contractual obligations to Customer and any Other Customers under LNG terminal use agreements, SABINE shall allocate the available capability of the Sabine Pass Facility to perform activities similar to the Services to Customer and Other Customers in a reasonable manner based on the ratio that the Maximum LNG Reception Quantity bears to the Aggregate Contracted Capacity for the remainder of such Contract Year. If a curtailment or temporary discontinuation of Services occurs under this Section 16.2, SABINE may direct Customer to adjust receipts of LNG and deliveries of Gas from Customer’s Inventory as the case may be; provided that SABINE shall use commercially reasonable efforts to implement such curtailment or discontinuance of Services among Customer and Other Customers as equitably as reasonably practicable under the circumstances. Notwithstanding the foregoing, SABINE shall have no responsibility to inform Transporters, LNG Vessels, Downstream Pipelines, LNG Suppliers, or any other Persons involved in the transaction as to such curtailment or temporary discontinuation of Services.

ARTICLE 17

ASSIGNMENT

17.1 Restrictions on Assignment

(a) Consent of Other Party Required. Except as otherwise provided in this Article 17, neither this Agreement nor any rights or obligations hereunder may be assigned by any Party without the prior written consent of the other Party, which consent shall not be unreasonably withheld.

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(b) Obligation of Assignee. If consent is granted pursuant to Section 17.1(a) or in the case of an assignment permitted under Section 17.2 (other than Section 17.2(c) or Section 17.2(d)), the assignee to such assignment must, as a condition to such assignment, deliver to the non-assigning Party its written undertaking to be bound by and perform all obligations of the assignor under this Agreement.

(c) Certain Restrictions. Notwithstanding anything to the contrary contained herein, (i) this Agreement shall not be assignable by Customer, in whole or in part, prior to the first business day after the occurrence of the Commercial Start Date as defined in the Existing Customer Agreement with TOTAL LNG USA, Inc.); (ii) no assignment shall be authorized hereunder that triggers or is likely to trigger the provisions of article 13 of that certain Omnibus Agreement between TOTAL LNG USA, Inc. and SABINE dated September 2, 2004.

17.2 Permitted Assignments

(a) Affiliates of SABINE. Notwithstanding the provisions of Section 17.1, SABINE may freely assign all of its rights and obligations under this Agreement to an Affiliate, upon notice to, but without requiring the consent of, Customer.

(b) Affiliates of Customer. Subject to the provisions of Section 17.1(c), and notwithstanding the provisions of Section 17.1(a), Customer may freely assign all of its rights and obligations under this Agreement to an Affiliate upon notice to, but without requiring the consent of, SABINE.

(c) Financing. Notwithstanding the provisions of Section 17.1, SABINE shall be entitled to assign, mortgage, or pledge all or any of its rights, interests, and benefits hereunder to secure payment of any indebtedness incurred or to be incurred in connection with the construction and term financing of the Sabine Pass Facility. Customer shall provide to the Lenders to whom such indebtedness is owed a consent to assignment or similar document in form and substance customary for similar financing transactions and agreed by such Lenders and Customer. Moreover, Customer agrees to enter into customary direct agreements with such Lenders in form and substance customary for similar financing transactions and agreed by such Lenders and Customer covering matters that are customary in project financings of this type, including Lender assignments or security rights with respect to this Agreement (appended hereto as Exhibit C), direct notices to Lenders and Lenders step-in/step-out rights; provided, however, in no event shall Customer be required to agree to any amendment to this Agreement or to provide (or cause to be provided) any guaranty or similar commitment in favor of Lenders, or any other Person. No assignment under this Section 17.2(c) shall serve as a novation to this Agreement.

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(d) Partial Assignments. Subject to the provisions of Section 17.1(c), Customer may assign a portion of the Services it is entitled to hereunder (a “Partial Assignment”) for any period of time up to and including the remainder of the Term, or all of its entitlements for a period of time that is less than the remaining Term, upon notice but without the prior consent of SABINE, to one or more assignees, provided that; and:

(i) the assignees deliver to SABINE the written undertaking required by Section 17.1(b);

(ii) Customer and all assignees designate one of them, or a third party, to act on behalf of Customer and all assignees as Scheduling Representative for purposes of giving and receiving all notices, statements and other communications from or to Customer and exercising all rights of Customer under this Agreement (including all rights under Clause A, Sections 2.3, 3.5, 8.2, 10.2, 11.3, 18.1, 20.1, and 20.2) jointly, without delay or hindrance to each Party’s performance of this Agreement; and

(iii) no Partial Assignment shall reduce the responsibility of Customer or SABINE in respect of the Services or increase SABINE’s responsibilities to Customer and the assignees under this Agreement. Customer shall remain liable for all payments due under this Agreement and SABINE shall continue to send all statements required under Article 11 to Customer. Customer shall indemnify and hold SABINE harmless from any Liabilities incurred by SABINE arising from a failure by Customer and all assignees to designate a Scheduling Representative under Section 17.2(d)(ii) above.

17.3 Assignment as Novation

(a) Except as provided in Section 17.2(b), an assignment under this Article 17 of all, but not less than all, of Customer’s or SABINE’s rights and obligations under this Agreement for the remaining Term of the Agreement shall not serve as a novation of this Agreement unless and until, but shall serve as a novation if:

(i) the assignee delivers to the non-assigning Party its written undertaking to be bound by and perform all obligations of the assignor (including the assumption of all liabilities of the assignor from the Effective Date through the date of such assignment) under this Agreement, as if it were the assignor; and

(ii) in the case of Customer, assignee having demonstrated to SABINE that its creditworthiness (including credit support from an irrevocable letter of credit, a parent guarantee or other security) at the time of the assignment is reasonably acceptable to SABINE. For the purposes of the preceding sentence, the creditworthiness at the time of the assignment of the proposed assignee shall be deemed acceptable to SABINE if: (i) the credit rating of such assignee is at such time equivalent to or better than no less

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than two of the following three ratings: “A3” by Moody’s Investor Service, “A-” by Standard and Poor’s and “A-” by Fitch Ratings; and (ii) the minimum market capitalization of such assignee is three billion five hundred million U.S. dollars ($3,500,000,000); or

(iii) in the case of SABINE, assignee having demonstrated to Customer that:

a. its creditworthiness at the time of the assignment is the same or better than the creditworthiness of SABINE; and

b. it has succeeded to substantially all of the assets comprising the Sabine Pass Facility and is willing and able to make available the Services to Customer.

(b) In the event of a novation, the assignee shall be deemed to be a Party to this Agreement for all purposes with respect to rights and obligations pertaining to operations hereunder from and after the effective date of the assignment and the assignor shall be relieved of all rights and obligations hereunder from and after the effective date of the assignment.

ARTICLE 18

TERMINATION

18.1 Early Termination Events

(a) Termination by Customer. Customer may terminate this Agreement pursuant to the other provisions of this Article 18, if SABINE has declared Force Majeure with respect to a period that is either projected by SABINE to extend for eighteen (18) months or has in fact extended eighteen (18) months.

(b) Termination by SABINE. SABINE may terminate this Agreement pursuant to the other provisions of this Article 18 if Customer passes a resolution, commences proceedings or has proceedings commenced against it (which are not stayed within sixty (60) days of service thereof) in the nature of bankruptcy or reorganization resulting from insolvency or for its liquidation of, or the appointment of a receiver, trustee in bankruptcy or liquidator of, its undertaking or assets.

(c) Notice. SABINE or Customer, as the case may be, shall give notice of its exercise of any termination right hereunder to the other Party.

(d) Cure. At any time after the expiration of a period of thirty (30) days after the terminating Party gives notice of termination pursuant to Section 18.1(c), such Party may terminate this Agreement with immediate effect by giving notice of such termination; provided, however, that the terminating Party may not terminate this Agreement if the circumstances giving rise to such termination right have been fully remedied or have ceased to apply.

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18.2 Other Termination Provisions

This Agreement is also subject to the termination provisions provided in Section 11.6.

18.3 Consequences of Termination

Termination of this Agreement under this Article 18 or any other provision of this Agreement shall be without prejudice to any other rights and remedies of either Party arising hereunder or by law or otherwise which arose or accrued prior to or as a result of such termination or by reason of default of either Party, provided, however, that in no event shall Customer be entitled to recover damages or pursue any other remedy against SABINE in relation to Services which would have been performed by SABINE after the date of termination by Customer.

ARTICLE 19

APPLICABLE LAW

The substantive laws of the State of New York, United States of America, exclusive of any conflicts of laws principles that could require the application of any other law, shall govern this Agreement for all purposes, including the resolution of all Disputes between or among the Parties.

ARTICLE 20

DISPUTE RESOLUTION

20.1 Dispute Resolution

(a) Arbitration. Any Dispute (other than a Dispute regarding measurement under Annex I or Annex II) shall be exclusively and definitively resolved through final and binding arbitration, it being the intention of the Parties that this is a broad form arbitration agreement designed to encompass all possible disputes.

(b) Rules. The arbitration shall be conducted in accordance with the International Arbitration Rules (the “Rules”) of the American Arbitration Association (“AAA”) (as then in effect).

(c) Number of Arbitrators. The arbitral tribunal (“Tribunal”) shall consist of three (3) arbitrators, who shall endeavor to complete the final hearing in the arbitration within six (6) months after the appointment of the last arbitrator.

(d) Method of Appointment of the Arbitrators. If there are only two (2) parties to the Dispute, then each party to the Dispute shall appoint one (1) arbitrator within thirty (30) days of the filing of the arbitration, and the two arbitrators so appointed shall select the presiding arbitrator within thirty (30) days after the latter of the two arbitrators has been appointed by the parties to the Dispute. If a party to the Dispute fails to appoint its Party-appointed arbitrator or if the two Party-appointed arbitrators cannot reach an agreement on the presiding arbitrator within the

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applicable time period, then the AAA shall serve as the appointing authority and shall appoint the remainder of the three arbitrators not yet appointed. If the arbitration is to be conducted by three arbitrators and there are more than two parties to the Dispute, then within thirty (30) days of the filing of the arbitration, all claimants shall jointly appoint one arbitrator and all respondents shall jointly appoint one arbitrator, and the two arbitrators so appointed shall select the presiding arbitrator within thirty (30) days after the latter of the two arbitrators has been appointed by the parties to the Dispute. For the purposes of appointing arbitrators under this Article 20: (i) Customer and all persons whose interest in this Agreement derives from them shall be considered as one Party; and (ii) SABINE and all persons whose interest in this Agreement derives from SABINE shall be considered as one Party. If either all claimants or all respondents fail to make a joint appointment of an arbitrator, or if the Party-appointed arbitrators cannot reach an agreement on the presiding arbitrator within the applicable time period, then the AAA as the appointing authority shall make the prescribed appointment.

(e) Consolidation. If the Parties initiate multiple arbitration proceedings under this Agreement, the subject matters of which are related by common questions of law or fact and which could result in conflicting awards or obligations, then either Party may request prior to the appointment of the arbitrators for such multiple or subsequent disputes that all such proceedings be consolidated into a single arbitral proceeding. Such request shall be directed to the AAA, which shall consolidate appropriate proceedings into a single proceeding unless consolidation would result in undue delay for the arbitration of the Disputes.

(f) Place of Arbitration. Unless otherwise agreed by all parties to the Dispute, the place of arbitration shall be Houston, Texas.

(g) Language. The arbitration proceedings shall be conducted in the English language, and the arbitrators shall be fluent in the English language.

(h) Entry of Judgment. The award of the arbitral tribunal shall be final and binding. Judgment on the award of the arbitral tribunal may be entered and enforced by any court of competent jurisdiction. The Parties agree that service of process for any action to enforce an award may be accomplished according to the procedures of Article 23, as well as any other procedure authorized by law.

(i) Notice. All notices required for any arbitration proceeding shall be deemed properly given if given in accordance with Article 23.

(j) Qualifications and Conduct of the Arbitrators. All arbitrators shall be and remain at all times wholly impartial, and, once appointed, no arbitrator shall have any ex parte communications with any of the parties to the Dispute concerning the arbitration or the underlying Dispute other than communications directly concerning the selection of the presiding arbitrator, where applicable.

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(k) Interim Measures. Any party to the Dispute may apply to a court in Harris County, Texas for interim measures: (i) prior to the constitution of the arbitral tribunal (and thereafter as necessary to enforce the arbitral tribunal’s rulings); or (ii) in the absence of the jurisdiction of the arbitral tribunal to rule on interim measures in a given jurisdiction. The Parties agree that seeking and obtaining such interim measures shall not waive the right to arbitration. The arbitrators (or in an emergency the presiding arbitrator acting alone in the event one or more of the other arbitrators is unable to be involved in a timely fashion) may grant interim measures including injunctions, attachments and conservation orders in appropriate circumstances, which measures may be immediately enforced by court order. Hearings on requests for interim measures may be held in person, by telephone, by video conference or by other means that permit the parties to the Dispute to present evidence and arguments.

(l) Costs and Attorneys’ Fees. The arbitral tribunal is authorized to award costs of the arbitration in its award, including: (i) the fees and expenses of the arbitrators; (ii) the costs of assistance required by the tribunal, including its experts; (iii) the fees and expenses of the administrator; (iv) the reasonable costs for legal representation of a successful Party; and (v) any such costs incurred in connection with an application for interim or emergency relief and to allocate those costs between the parties to the Dispute. The costs of the arbitration proceedings, including attorneys’ fees, shall be borne in the manner determined by the arbitral tribunal.

(m) Interest. The award shall include pre-award and post-award interest, as determined by the arbitral award, from the date of any default or other breach of this Agreement until the arbitral award is paid in full. Interest shall accrue at the Base Rate.

(n) Currency of Award. The arbitral award shall be made and payable in United States dollars, free of any tax or other deduction.

(o) Waiver of Challenge to Decision or Award. To the extent permitted by law, the Parties hereby waive any right to appeal from or challenge any arbitral decision or award, or to oppose enforcement of any such decision or award before a court or any governmental authority, except with respect to the limited grounds for modification or non-enforcement provided by any applicable arbitration statute or treaty.

(p) Confidentiality. Any arbitration or expert determination relating to a Dispute (including a settlement resulting from an arbitral award, documents exchanged or produced during an arbitration proceeding, and memorials, briefs or other documents prepared for the arbitration) shall be confidential and may not be disclosed by the Parties, their employees, officers, directors, counsel, consultants, and expert witnesses, except (in accordance with Article 21) to the extent necessary to enforce this Section 20.1 or any arbitration award, to enforce other rights of a party to the Dispute, or as required by law; provided, however, that breach of this confidentiality provision shall not void any settlement, expert determination or award.

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20.2 Expert Determination

(a) General. In the event of any disagreement between the Parties regarding a measurement under Annex I or Annex II (a “Measurement Dispute”), the Parties hereby agree that such Measurement Dispute shall be resolved by an expert selected as provided in this Section 20.2. The expert is not an arbitrator of the Measurement Dispute and shall not be deemed to be acting in an arbitral capacity. The Party desiring an expert determination shall give the other Party to the Measurement Dispute notice of the request for such determination. If the Parties to the Measurement Dispute are unable to agree upon an expert within ten (10) days after receipt of the notice of request for an expert determination, then, upon the request of any of the Parties to the Measurement Dispute, the International Centre for Expertise of the International Chamber of Commerce shall appoint such expert and shall administer such expert determination through the ICC’s Rules for Expertise. The expert shall be and remain at all times wholly impartial, and, once appointed, the expert shall have no ex parte communications with any of the Parties to the Measurement Dispute concerning the expert determination or the underlying Measurement Dispute. The Parties to the Measurement Dispute shall cooperate fully in the expeditious conduct of such expert determination and provide the expert with access to all facilities, books, records, documents, information and personnel necessary to make a fully informed decision in an expeditious manner. Before issuing a final decision, the expert shall issue a draft report and allow the Parties to the Measurement Dispute to comment on it. The expert shall endeavor to resolve the Measurement Dispute within thirty (30) days (but no later than sixty (60) days) after his appointment, taking into account the circumstances requiring an expeditious resolution of the matter in dispute.

(b) Final and Binding. The expert’s decision shall be final and binding on the Parties to the Measurement Dispute unless challenged in an arbitration pursuant to Section 20.1 within thirty (30) days of the date the expert’s decision. If challenged: (i) the decision shall remain binding and be implemented unless and until finally replaced by an award of the arbitrators; (ii) the decision shall be entitled to a rebuttable presumption of correctness; and (iii) the expert shall not be appointed in the arbitration as an arbitrator or as advisor to either Party without the written consent of both Parties.

(c) Arbitration of Expert Determination. In the event that a Party requests expert determination for a Measurement Dispute which raises issues that require determination of other matters in addition to correct measurement under Annex I or Annex II, then either Party may elect to refer the entire Measurement Dispute for arbitration under Section 20.1. In such case, the arbitrators shall be competent to make any measurement determination that is part of a Dispute. An expert determination not referred to arbitration shall proceed and shall not be stayed during the pendency of an arbitration.

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ARTICLE 21

CONFIDENTIALITY

21.1 Confidentiality Obligation

Neither this Agreement nor information or documents that come into the possession of a Party by means of the other Party in connection with the performance of this Agreement may be used or communicated to Persons (other than the Parties) without the mutual written agreement of the Parties, except that either Party shall have the right to disclose such information or documents without obtaining the other Party’s prior consent in any of the situations described below:

(a) accountants, other professional consultants or underwriters, provided such disclosure is solely to assist the purpose for which the aforesaid were so engaged and further provided that such Persons agree to hold such information or documents under terms of confidentiality equivalent to this Section 21.1, and for the benefit of the Parties;

(b) Lenders and other providers or prospective providers of finance to SABINE in relation to the Sabine Pass Facility, provided that such Persons agree to hold such information or documents confidential, and for the benefit of the Parties, for a period of at least three (3) years (excepting information in connection with the Fee, which shall be held confidential during the Term);

(c) bona fide prospective purchasers of all or a part of a Party’s or its Affiliate’s business, and bona fide prospective assignees of all or part of a Party’s interest in this Agreement, provided that such Persons agree to hold such information or documents under terms of confidentiality equivalent to this Section 21.1, and for the benefit of the Parties;

(d) to legal counsel, provided such disclosure is solely to assist the purpose for which the aforesaid were so engaged;

(e) if required by any court of law or any law, rule, or regulation, or if requested by a Governmental Authority (including the United States Securities and Exchange Commission) having or asserting jurisdiction over a Party and having or asserting authority to require such disclosure in accordance with that authority, or pursuant to the rules of any recognized stock exchange or agency established in connection therewith. Seller further acknowledges and agrees that complete copies of this Agreement, with attachments, and any and all related agreements and material amendments hereto may be filed by Cheniere Energy, Inc. with the United States Securities and Exchange Commission as material agreements or amendments in accordance with applicable securities laws and regulations;

(f) to prospective assignees permitted under Article 17, to prospective and actual LNG Suppliers and to any prospective and actual purchasers under the Customer’s Gas sales contracts from Customer’s Inventory, in each case only to the extent required for the execution and/or administration of such contracts, and

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provided that such Persons agree to hold such information or documents under terms of confidentiality equivalent to this Section 21.1, and for the benefit of the Parties;

(g) to its Affiliates, its shareholders and partners, or its shareholders’ and partners’ Affiliates, provided that such recipient entity has a bona fide business need for such information and agrees to hold such information or documents under terms of confidentiality equivalent to this Section 21.1;

(h) to any Governmental Authority to the extent such disclosure assists SABINE and Customer in obtaining Approvals;

(i) to an expert in connection with the resolution of a Dispute pursuant to Section 20.2 or to an arbitration tribunal in connection with the resolution of a Dispute under Section 20.1; and

(j) to the extent any such information or document has entered the public domain other than through the fault or negligence of the Party making the disclosure.

21.2 Public Announcements

(a) General. Neither Party may issue or make any public announcement, press release or statement regarding this Agreement unless, prior to the release of the public announcement, press release or statement, such Party furnishes the other Party with a copy of such announcement, press release or statement, and obtains the approval of the other Party, such approval not to be unreasonably withheld; provided that, notwithstanding any failure to obtain such approval, no Party shall be prohibited from issuing or making any such public announcement, press release or statement if in the sole discretion of the disclosing Party it is deemed appropriate to do so in order to comply with the applicable laws, rules or regulations of any Governmental Authority, legal proceedings or stock exchange having jurisdiction over such Party.

(b) SABINE Promotional Materials. Notwithstanding any provision in Section 21.2(a) to the contrary, either Party may, with the consent of the other Party not to be unreasonably withheld, use the following in external announcements and publications: (i) information concerning the signing of this Agreement; (ii) the general nature of the Services; and (iii) the general nature of Customer’s involvement in the Sabine Pass Facility project.

ARTICLE 22

REPRESENTATIONS AND WARRANTIES

As of the date hereof and until the expiration of this Agreement, each Party represents and warrants to the other Party that:

(a) It is and shall remain duly formed and in good standing under the laws of the jurisdiction of its organization;

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(b) It has the requisite power, authority and legal right to execute and deliver, and to perform its obligations under, this Agreement;

(c) It has not, in connection with the execution of this Agreement, incurred any liability to any financial advisor, broker or finder for any financial advisory, brokerage, finder’s or similar fee or commission for which it or any of its Affiliates could be liable;

(d) Neither the execution, delivery nor performance of this Agreement violates or will violate, results or will result in a breach of or constitutes or will constitute a default under any provision of it’s organizational documents, any law, judgment, order, decree, rule or regulation of any court, administrative agency or other instrumentality of any Governmental Authority or of any other material agreement or instrument to which Customer is a party;

(e) Its obligations under this Agreement constitute its legal, valid and binding obligations, enforceable in accordance with its terms (subject to applicable bankruptcy, reorganization, insolvency, moratorium or similar laws affecting creditors’ rights regardless of whether enforcement is sought in a proceeding in equity or at law and an implied covenant of good faith and fair dealing).

(f) All governmental and other authorizations, approvals, consents, notices and filings that are required to have been obtained or submitted by it with respect to this Agreement have been obtained or submitted and are in full force and effect, and all conditions of any such authorizations, approvals, consents, notices and filings have been complied with.

ARTICLE 23

NOTICES

Except as otherwise specifically provided, all notices authorized or required between the Parties by any of the provisions of this Agreement shall be in writing (in English) and delivered in person or by courier service or by any electronic means of transmitting written communications which provides written confirmation of complete transmission, and addressed to such Party. Oral communication does not constitute notice for purposes of this Agreement, and e-mail addresses and telephone numbers for the Parties are listed as a matter of convenience only. The foregoing notwithstanding, notices given from LNG Vessels at sea may be given by radio, and notices required under Article 5 may be given by e-mail. A notice given under any provision of this Agreement shall be deemed delivered only when received by the Party to whom such notice is directed, and the time for such Party to deliver any notice in response to such originating notice shall run from the date the originating notice is received. “Received” for purposes of this Article 23 shall mean actual delivery of the notice, or delivery of the notice to the address of the Party specified in Clause D or, in the event notice was given by radio from an LNG Vessel at sea, actual receipt of the communication by radio, or to be thereafter notified in accordance with

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this Article 23. Each Party shall have the right to change its address at any time and/or designate that copies of all such notices be directed to another Person at another address by giving written notice thereof to the other Party.

ARTICLE 24

MISCELLANEOUS

24.1 Amendments

This Agreement may not be amended, modified, varied or supplemented except by an instrument in writing signed by SABINE and Customer.

24.2 Approvals

Each Party shall use reasonable endeavors to maintain in force all Approvals necessary for its performance under this Agreement. Customer and SABINE shall cooperate fully with each other wherever necessary for this purpose.

24.3 Successors and Assigns

This Agreement shall inure to the benefit of and be binding upon the respective successors and permitted assigns of the Parties.

24.4 Waiver

No failure to exercise or delay in exercising any right or remedy arising from this Agreement shall operate or be construed as a waiver of such right or remedy. Performance of any condition or obligation to be performed hereunder shall not be deemed to have been waived or postponed except by an instrument in writing signed by the Party who is claimed to have granted such waiver or postponement. No waiver by either Party shall operate or be construed as a waiver in respect of any failure or default not expressly identified by such written waiver, whether of a similar or different character, and whether occurring before or after that waiver.

24.5 No Third Party Beneficiaries

The interpretation of this Agreement shall exclude any rights under legislative provisions conferring rights under a contract to Persons not a party to that contract. Nothing in this Agreement shall otherwise be construed to create any duty to, or standard of care with reference to, or any liability to, any Person other than a Party.

24.6 Rules of Construction

(a) Drafting. Each provision of this Agreement shall be construed as though all Parties participated equally in the drafting of the same. Consequently, the Parties acknowledge and agree that any rule of construction that a document is to be construed against the drafting Party shall not be applicable to this Agreement.

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(b) Priority.

(i) In the event of a conflict between the terms of this Agreement excluding Annexes I and II and Exhibits A, B and C (the “Base Agreement”) and the terms of Annexes I and II and Exhibits A, B and C then all terms of the Base Agreement shall take precedence over Annexes I and II and Exhibits A, B and C.

(ii) In the event that any conflict arises between this Agreement and the Sabine Pass Marine Operations Manual, this Agreement shall prevail. In the event that any conflict arises between this Agreement and the Sabine Pass Services Manual, this Agreement shall prevail.

24.7 Survival of Rights

Any termination or expiration of this Agreement shall be without prejudice to any rights, remedies, obligations and liabilities which may have accrued to a Party pursuant to this Agreement or otherwise under applicable law. All rights or remedies which may have accrued to the benefit of either Party (and any of this Agreement’s provisions necessary for the exercise of such accrued rights or remedies) prior to the termination or expiration of this Agreement shall survive such termination or expiration. Furthermore, the provisions of Article 11, Article 12, Article 14, Article 19, Article 20, Article 21, Article 23, and Article 24 shall survive the termination or expiration of this Agreement.

24.8 Rights and Remedies

Except where this Agreement expressly provides to the contrary, the rights and remedies contained in this Agreement are cumulative and not exclusive of any rights and remedies provided by law.

24.9 Interpretation

(a) Headings. The topical headings used in this Agreement are for convenience only and shall not be construed as having any substantive significance or as indicating that all of the provisions of this Agreement relating to any topic are to be found in any particular Article or that an Article relates only to the topical heading.

(b) Singular and Plural. Reference to the singular includes a reference to the plural and vice versa.

(c) Gender. Reference to any gender includes a reference to all other genders.

(d) Article. Unless otherwise provided, reference to any Article, Section, Annex or Exhibit means an Article, Section, Annex or Exhibit of this Agreement. In addition, reference to a Clause means a reference to a Clause in Part One and reference to an Article or Section means a reference to an Article or Section of Part Two.

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(e) Include. The words “include” and “including” shall mean include or including without limiting the generality of the description preceding such term and are used in an illustrative sense and not a limiting sense.

(f) Time Periods. References to “day,” “month,” “quarter” and “year” shall, unless otherwise stated or defined, mean a day, month, quarter and year of the Gregorian calendar, respectively. For the avoidance of doubt, a “day” shall commence at 24:00 midnight.

(g) Statutory References. Unless the context otherwise requires, any reference to a statutory provision is a reference to such provision as amended or re-enacted or as modified by other statutory provisions from time to time and includes subsequent legislation and regulations made under the relevant statute.

(h) Currency. References to United States dollars shall be a reference to the lawful currency from time to time of the United States of America.

24.10 Disclaimer of Agency

The rights, duties, obligations and liabilities of the Parties under this Agreement shall be individual, not joint or collective. It is not the intention of the Parties to create, nor shall this Agreement be deemed or construed to create, nor shall the Parties report for any purpose any transaction occurring pursuant to this Agreement as: (a) a partnership, joint venture or other association or a trust; nor (b) a lease or sales transaction with respect to any portion of the Sabine Pass Facility. This Agreement shall not be deemed or construed to authorize any Party to act as an agent, servant or employee for the other Party for any purpose whatsoever except as explicitly set forth in this Agreement. In their relations with each other under this Agreement, the Parties shall not be considered fiduciaries.

24.11 No Sovereign Immunity

Any Party that now or hereafter has a right to claim sovereign immunity for itself or any of its assets hereby waives any such immunity to the fullest extent permitted by the laws of any applicable jurisdiction. This waiver includes immunity from: (a) any expert determination or arbitration proceeding commenced or to be commenced pursuant to this Agreement; (b) any judicial, administrative or other proceedings to aid the expert determination or arbitration commenced pursuant to this Agreement; and (c) any effort to confirm, enforce, or execute any decision, settlement, award, judgment, service of process, execution order or attachment (including pre-judgment attachment) that results from an expert determination, mediation, arbitration or any judicial or administrative proceedings commenced pursuant to this Agreement. Each Party acknowledges that its rights and obligations hereunder are of a commercial and not a governmental nature.

24.12 Severance of Invalid Provisions

If and for so long as any provision of this Agreement shall be deemed to be judged invalid for any reason whatsoever, such invalidity shall not affect the validity or

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operation of any other provision of this Agreement except only so far as shall be necessary to give effect to the construction of such invalidity, and any such invalid provision shall be deemed severed from this Agreement without affecting the validity of the balance of this Agreement.

24.13  Compliance with Laws

In performance of their respective obligations under this Agreement, each Party agrees to comply with all applicable laws, statutes, rules, regulations, judgments, decrees, injunctions, writs and orders, and all interpretations thereof, of all Governmental Authorities having jurisdiction over such Party.

24.14  Conflicts of Interest

SABINE shall avoid any conflict between its own interests and the interests of Customer in relation to obtaining LNG terminalling services from the Sabine Pass Facility. In this regard, SABINE shall not become one of the Other Customers during the Term hereof unless Customer has first consented in writing (such consent not to be unreasonably withheld or delayed) to such expanded business role by SABINE. In no event shall: (a) any of SABINE’s joint venture partners or affiliated entities of any kind be restricted from becoming one of the Other Customers during the Term hereof; or (b) any partner, shareholder, member, or other equity owner of SABINE be restricted from becoming one of the Other Customers during the Term hereof. Except as provided above, the Parties and their Affiliates are free to engage or invest (directly or indirectly) in an unlimited number of activities or businesses, any one or more of which may be related to or in competition with the business activities contemplated under this Agreement, without having or incurring any obligation to offer any interest in such business activities to the other Party.

24.15  Expenses

Each Party shall be responsible for and bear all of its own costs and expenses incurred in connection with the preparation and negotiation of this Agreement.

24.16  Scope

This Agreement constitutes the entire agreement between the Parties relating to the subject matter hereof and supersedes and replaces any provisions on the same subject contained in any other agreement between the Parties, whether written or oral, prior to the date of the original execution hereof.

24.17  Counterpart Execution

This Agreement may be executed in any number of counterparts and each such counterpart shall be deemed an original Agreement for all purposes; provided that no Party shall be bound to this Agreement unless and until both Parties have executed a counterpart. For purposes of assembling all counterparts into one document, Customer is authorized to detach the signature page from one or more counterparts and, after signature thereof by the respective Party, attach each signed signature page to a counterpart.

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ANNEX I

MEASUREMENTS AND TESTS FOR LNG AT RECEIPT POINT

1. Parties to Supply Devices

a) General. Unless otherwise agreed, Customer and SABINE shall supply equipment and conform to procedures that are in accordance with the latest appropriate International Organization for Standards (“ISO”) documents.

b) Customer Devices. Customer or Customer’s agent shall supply, operate and maintain, or cause to be supplied, operated and maintained, suitable gauging devices for the liquid level in LNG tanks of the LNG Vessels, pressure and temperature measuring devices, and any other measurement or testing devices which are incorporated in the structure of LNG vessels or customarily maintained on board ship.

c) SABINE Devices. SABINE shall supply, operate and maintain, or cause to be supplied, operated and maintained, devices required for collecting samples and for determining quality and composition of the LNG and any other measurement or testing devices which are necessary to perform the measurement and testing required hereunder at the Sabine Pass Facility.

d) Dispute. Any Dispute arising under this Annex I shall be submitted to an Expert under Section 20.2.

2. Selection of Devices

All devices provided for in this Annex I shall be approved by SABINE, acting as a Reasonable and Prudent Operator. The required degree of accuracy (which shall in any case be within the permissible tolerances defined herein and in the applicable standards referenced herein) of such devices selected shall be mutually agreed upon by Customer and SABINE. In advance of the use of any device, the Party providing such device shall cause tests to be carried out to verify that such device has the required degree of accuracy.

3. Verification of Accuracy and Correction for Error

a) Accuracy. Accuracy of devices used shall be tested and verified at the request of either Party, including the request by a Party to verify accuracy of its own devices. Each Party shall have the right to inspect at any time the measurement devices installed by the other Party, provided that the other Party is notified in advance. Testing shall be performed only when both Parties are represented, or have received adequate advance notice thereof, using methods recommended by the manufacturer or any other method agreed to by SABINE and Customer. At the request of any Party hereto, any test shall be witnessed and verified by an independent surveyor mutually agreed upon by Customer and SABINE. Permissible tolerances shall be as defined herein or as defined in the applicable standards referenced herein.

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b) Inaccuracy. Inaccuracy of a device exceeding the permissible tolerances shall require correction of previous recordings, and computations made on the basis of those recordings, to zero error with respect to any period which is definitely known or agreed upon by the Parties as well as adjustment of the device. All invoices issued during such period shall be amended accordingly to reflect such correction, and an adjustment in payment shall be made between Customer and SABINE. If the period of error is neither known nor agreed upon, and there is no evidence as to the duration of such period of error, corrections shall be made and invoices amended for each receipt of LNG made during the last half of the period since the date of the most recent calibration of the inaccurate device. However, the provisions of this Paragraph 3 shall not be applied to require the modification of any invoice that has become final pursuant to Section 11.7.

c) Costs and Expenses of Test Verification. All costs and expenses for testing and verifying SABINE’s measurement devices shall be borne by SABINE, and all costs and expenses for testing and verifying Customer’s measurement devices shall be borne by Customer. The fees and charges of independent surveyors for measurements and calculations shall be borne directly by Customer.

4. Tank Gauge Tables of LNG Vessels

a) Initial Calibration. Customer shall arrange or caused to be arranged, for each tank of each LNG Vessel, a calibration of volume against tank level. Customer shall provide SABINE or its designee, or cause SABINE or its designee to be provided, with a certified copy of tank gauge tables for each tank of each LNG Vessel verified by a competent impartial authority or authorities mutually agreed upon by the Parties. Such tables shall include correction tables for list, trim, tank contraction and any other items requiring such tables for accuracy of gauging.

Tank gauge tables prepared pursuant to the above shall indicate volumes in cubic meters expressed to the nearest thousandth (1/1000), with LNG tank depths expressed in meters to the nearest hundredth (1/100).

b) Presence of Representatives. SABINE and Customer shall each have the right to have representatives present at the time each LNG tank on each LNG Vessel is volumetrically calibrated.

c) Recalibration. If the LNG tanks of any LNG Vessel suffer distortion of such nature as to create a reasonable doubt regarding the validity of the tank gauge tables described herein (or any subsequent calibration provided for herein), Customer or Customer’s agent shall recalibrate the damaged tanks, and the vessel shall not be employed as an LNG Vessel hereunder until appropriate corrections are made. If mutually agreed between Customer and SABINE representatives, recalibration of damaged tanks can be deferred until the next time when such

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damaged tanks are warmed for any reason, and any corrections to the prior tank gauge tables will be made from the time the distortion occurred. If the time of the distortion cannot be ascertained, the Parties shall mutually agree on the time period for retrospective adjustments.

5. Units of Measurement and Calibration

The Parties shall co-operate in the design, selection and acquisition of devices to be used for measurements and tests in order that all measurements and tests may be conducted in the SI system of units, except for the quantity delivered which is expressed in MMBTU, the Gross Heating Value (Volume Based) which is expressed in BTU/SCF and the pressure which is expressed in millibar and temperature in Celsius. In the event that it becomes necessary to make measurements and tests using a new system of units of measurements, the Parties shall establish agreed upon conversion tables.

6. Accuracy of Measurement

All measuring equipment must be maintained, calibrated and tested in accordance with the manufacturer’s recommendations. In the absence of a manufacturer’s recommendation, the minimum frequency of calibration shall be one hundred eighty (180) days, unless otherwise mutually agreed between the Parties. Documentation of all tests and calibrations will be made available by the Party performing the same to the other Party. Acceptable accuracy and performance tolerances shall be:

a) Liquid Level Gauging Devices.

Each LNG tank of the LNG Vessel shall be equipped with primary and secondary liquid level gauging devices as per Paragraph 7(b) of this Annex I.

The measurement accuracy of the primary gauging devices shall be plus or minus seven point five (± 7.5) millimeters and the secondary liquid level gauging devices shall be plus or minus ten (± 10) millimeters.

The liquid level in each LNG tank shall be logged or printed.

b) Temperature Gauging Devices.

The temperature of the LNG and of the vapor space in each LNG tank shall be measured by means of a number of properly located temperature measuring devices sufficient to permit the determination of average temperature.

The measurement accuracy of the temperature gauging devices shall be as follows:

(i) in the temperature range of minus one hundred sixty five to minus one hundred forty degree Celsius (-165C to -140°C), the accuracy shall be plus or minus zero point two degree Celsius (± 0.2 °C);

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(ii) in the temperature range of minus one hundred forty to plus forty degree Celsius (-140C to +40 °C), the accuracy shall be plus or minus one point five degree Celsius (± 1.5 °C).

The temperature in each LNG tank shall be logged or printed.

c) Pressure Gauging Devices.

Each LNG tank of the LNG Vessel shall have one (1) absolute pressure gauging device.

The measurement accuracy of the pressure gauging device shall be plus or minus one percent (± 1%) of the measuring range.

The pressure in each LNG tank shall be logged or printed.

d) List and Trim Gauging Devices.

A list gauging device and a trim gauging device shall be installed. These shall be interfaced with the custody transfer system.

The measurement accuracy of the list and the trim gauging devices shall be better than plus or minus zero point zero five (±0.05) degrees for list and plus or minus zero point zero one (± 0.01) degrees for trim.

7. Gauging and Measuring LNG Volumes Delivered

a) Gauge Tables. Upon SABINE’s representative and the independent surveyor, if present, arriving on board the LNG Vessel prior to the commencement of or during unloading, Customer or Customer’s representative shall make available to them a certified copy of tank gauge tables for each tank of the LNG Vessel.

b) Gauges. Volumes of LNG delivered pursuant to this Agreement shall be determined by gauging the LNG in the tanks of the LNG Vessels before and after unloading. Each LNG Vessel’s tank shall be equipped with a minimum of two (2) sets of level gauges, each set utilizing a different measurement principle. Comparison of the two (2) systems, designated as Primary and Secondary Measurement Systems, shall be performed from time to time to ensure compliance with the acceptable performance tolerances stated herein.

c) Gauging Process. Gauging the liquid in the tanks of the LNG Vessels and measuring of liquid temperature, vapor temperature and vapor pressure in each LNG tank, trim and list of the LNG Vessels, and atmospheric pressure shall be performed, or caused to be performed, by Customer before and after unloading. SABINE’s representative shall have the right to be present while all measurements are performed and shall verify the accuracy and acceptability of all such measurements. The first gauging and measurements shall be made immediately before the commencement of unloading. The second gauging and

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measurements shall take place immediately after the completion of unloading. The liquid level in the LNG Vessel before and after the unloading shall be determined by at least two (2) separate tank gaugings to be conducted at least fifteen (15) minutes apart.

d) Records. Copies of gauging and measurement records shall be furnished to SABINE immediately upon completion of unloading.

e) Gauging Liquid Level of LNG. The level of the LNG in each LNG tank of the LNG Vessel shall be gauged by means of the primary gauging device installed in the LNG Vessel for that purpose. The level of the LNG in each tank shall be logged or printed.

Measurement of the liquid level in each LNG tank of the LNG Ship shall be made to the nearest millimeter by using the primary liquid level gauging devices. Should the primary devices fail, the secondary device shall be used.

Five (5) readings shall be made following manufacturer’s recommendations on reading interval. The arithmetic average of the readings rounded to the nearest millimeter using one (1) decimal place shall be deemed the liquid level.

f) Determination of Temperature. The temperature of the LNG and of the vapor space in each LNG tank shall be measured by means of a sufficient number of properly located temperature measuring devices to permit the determination of average temperature. Temperatures shall be measured at the same time as the liquid level measurements and shall be logged or printed.

In order to determine the temperature of liquid and vapor respectively in the LNG Vessel one (1) reading shall be taken at each temperature gauging device in each LNG tank. An arithmetic average of such readings rounded to the nearest zero point one degree Celsius (0.1 °C) using two (2) decimal places with respect to vapor and liquid in all LNG tanks shall be deemed the final temperature of the vapor and liquid respectively.

Customer shall cause each cargo tank in the LNG Vessel to be provided with a minimum of five (5) temperature measuring devices. One such measuring device shall be located in the vapor space at the top of each cargo tank, one near the bottom of each cargo tank and the remainder distributed at appropriate intervals from the top to the bottom of the cargo tank. These devices shall be used to determine the average temperatures of the liquid cargo and the vapor in the cargo tank.

The average temperature of the vapor in an LNG Vessel shall be determined immediately before unloading by means of the temperature measuring devices specified above at the same time as when the liquid level is measured. The temperature measuring devices shall be fully surrounded by the vapor. This determination shall be made by taking the temperature readings of the temperature measuring devices in question to the nearest zero point zero one degrees Celsius (0.01°C), and if more than one of the devices are fully surrounded by the vapor, by averaging those readings, and rounding to one (1) decimal place.

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g) Determination of Pressure. The pressure of the vapor in each LNG tank shall be determined by means of pressure measuring devices installed in each LNG tank of the LNG Vessels. The atmospheric pressure shall be determined by readings from the standard barometer installed in the LNG Vessels. Pressures shall be measured at the same time as the liquid level measurements, and shall be logged or printed.

Customer shall cause the LNG Vessel to be provided with pressure measuring equipment capable of determining the absolute pressure of the vapor in each cargo tank with an accuracy equal to or better than plus or minus one percent (± 1%) of the measuring range.

The pressure of the vapor in an LNG Vessel shall be determined immediately before unloading at the same time as when the liquid level is measured.

Such determination shall be made by taking the pressure readings of the pressure measuring devices to the nearest millibar, then averaging these readings and rounding to a whole millibar.

h) Determination of Density. The LNG density shall be calculated using the method described within ISO 6976-2000, Calculation of calorific values, density, relative density and Wobbe Index from composition. This method shall be updated to conform to any official published revision of that document. Should any improved data, method of calculation or direct measurement device become available which is acceptable to both Customer and SABINE, such improved data, method or device shall then be used. If density is determined by measurements, the results shall be measured at the same time as the liquid level measurements and shall be logged or printed.

8. Samples for Quality Analysis

a) General. Flow proportional representative liquid samples shall be collected from an appropriate point located as close as practical to the unloading line starting two (2) hours after the beginning of transfer and ending two (2) hours before the end of transfer. Samples taken when biphasic or overheated LNG is suspected to be in the main transfer line will be disregarded. These incremental samples will be passed through a vaporizer, and samples of the vaporized liquid will be analyzed. The resulting analyses, which are proportional to time, will be mathematically flow rate weighted to yield an analysis that is representative of the unloaded Cargo. This flow rate weighted analysis shall be used for all appropriate calculations associated with the delivered Cargo. Should the automatic sampling system fail during the unloading, manual samples shall be collected and analyzed for accounting purposes.

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b) Manual Samples. Prior to the end of the unloading cycle, two (2) spot samples shall be collected from the vaporizer. Spot samples shall be collected in accordance with Gas Processors Association (“GPA”) Standard 2166 - Methods for Obtaining Gas Samples for Analysis by Gas Chromatography - or by other mutually agreeable methods. The samples shall be properly labeled and then distributed to Customer and SABINE. SABINE shall retain one (1) sample for a period of thirty (30) days, unless the analysis is in dispute. If the analysis is in dispute, the sample will be retained until the dispute is resolved.

Sampling and analysis methods and procedures that differ from the above may be employed with the mutual agreement of the Parties.

9. Quality Analysis

a) Certification and Deviation. Chromatograph calibration gasses shall be provided and their composition certified by an independent third party. From time to time, deviation checks shall be performed to verify the accuracy of the gas composition mole percentages and resulting calculated physical properties. Analyses of a sample of test gas of known composition resulting when procedures that are in accordance with the above mentioned standards have been applied will be considered as acceptable if the resulting calculated gross real heating value is within plus or minus zero point three percent (± 0. 3%) of the known gross real heating value of the test gas sample. If the deviation exceeds the tolerance stated, the gross real heating value, relative density and compressibility previously calculated will be corrected immediately. Previous analyses will be corrected to the point where the error occurred, if this can be positively identified to the satisfaction of both Parties. Otherwise it shall be assumed that the drift has been linear since the last recalibration and correction shall be based on this assumption.

b) GPA Standard 2261. All samples shall be analyzed by SABINE to determine the molar fraction of the hydrocarbon and other components in the sample by gas chromatography using a mutually agreed method in accordance with GPA Standard 2261 - Method of Analysis for Gas and Similar Gaseous Mixtures by Gas Chromatography, current as of January 1, 1990 and as periodically updated or as otherwise mutually agreed by the Parties. If better standards for analysis are subsequently adopted by GPA or other recognized competent impartial authority, upon mutual agreement of Customer and SABINE, they shall be substituted for the standard then in use, but such substitution shall not take place retroactively. A calibration of the chromatograph or other analytical instrument used shall be performed by SABINE immediately prior to the analysis of the sample of LNG delivered. SABINE shall give advance notice to Customer of the time SABINE intends to conduct a calibration thereof, and Customer shall have the right to have a representative present at each such calibration; provided, however, SABINE will not be obligated to defer or reschedule any calibration in order to permit the representative of Customer to be present.

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c) GPA Standard 2377 and 2265. SABINE shall determine the presence of Hydrogen Sulfide (H₂S) by use of GPA Standard 2377 - Test of Hydrogen Sulfide and Carbon Dioxide in Gas Using Length of Stain Tubes. If necessary, the concentration of H₂S and total sulfur will be determined using one or more of the following methods as is appropriate: gas chromatography, Gas Processors Standard 2265 - Standard for Determination of Hydrogen Sulfide and Mercaptan Sulfur in Gas (Cadmium Sulfate - Iodometric Titration Method) or any other method that is mutually acceptable.

10. Operating Procedures

a) Notice. Prior to conducting operations for measurement, gauging, sampling and analysis provided in this Annex I, the Party responsible for such operations shall notify the appropriate representatives of the other Party, allowing such representatives reasonable opportunity to be present for all operations and computations; provided that the absence of the other Party’s representative after notification and opportunity to attend shall not prevent any operations and computations from being performed.

b) Independent Surveyor. At the request of either Party any measurement, gauging, sampling and analysis shall be witnessed and verified by an independent surveyor mutually agreed upon by Customer and SABINE. The results of such surveyor’s verifications shall be made available promptly to each Party.

c) Preservation of Records. All records of measurement and the computed results shall be preserved by the Party responsible for taking the same, or causing the same to be taken, and made available to the other Party for a period of not less than three (3) years after such measurement and computation.

11. Quantities Delivered

a) Calculation of MMBTU Quantities. The quantity of MMBTU delivered shall be calculated by SABINE and verified by Customer. Either Party may, at its own expense, require the measurements and calculations and/or their verification by an independent surveyor, mutually agreed upon by the Parties. Consent to an independent surveyor proposed by a Party shall not be unreasonably withheld by the other Party.

b) Determination of Gross Real Heating Value. All component values shall be in accordance with the latest revision of ISO 6579 and the latest revision of the reference standards therein.

c) Determination of Volume of LNG Unloaded.

(i) The LNG volume in the tanks of the LNG Vessel before and after unloading (valves have to be closed) shall be determined by gauging on the basis of the tank gauge tables provided for in Paragraph 6. The volume of LNG remaining in the tanks after unloading of the LNG Vessel

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shall be subtracted from the volume before unloading and the resulting volume shall be taken as the volume of the LNG delivered from the LNG Vessel.

The volume of LNG stated in cubic meters to the nearest zero point zero zero one (0.001) cubic meter, shall be determined by using the tank gauge tables and by applying the volume corrections set forth therein.

(i) Gas returned to the LNG Vessel during unloading shall not be deemed to be volume unloaded for Customer’s account.

(ii) If failure of the primary gauging and measuring devices of an LNG Vessel should make it impossible to determine the LNG volume, the volume of LNG unloaded shall be determined by gauging the liquid level using the secondary gauging and measurement devices. If an LNG Vessel is not so equipped, the volume of LNG delivered shall be determined by gauging the liquid level in SABINE’s onshore LNG storage tanks immediately before and after unloading the LNG Vessel, and such volume shall have added to it an estimated LNG volume, agreed upon by the Parties, for boil-off from such tanks during the unloading of such LNG Vessel and have added to it the volume of any LNG that has been pumped from the LNG Vessel’s tanks during unloading. SABINE shall provide Customer, or cause Customer to be provided with, a certified copy of tank gauge tables for each onshore LNG tank which is to be used for this purpose, such tables to be verified by a competent impartial authority.

12. Calculations

The calculation procedures contained in this Section are generally in accordance with the Institute of Petroleum Measurement Manual, Part XII, the Static Measurement of Refrigerated Hydrocarbon Liquids, Section 1, IP 251/76.

d	=	density of LNG unloaded at the prevailing composition and temperature Tl in kg/m3, rounded to two (2) decimal places, calculated according to the method specified in Paragraph 12.1 of this Annex I.
Hi	=	gross heating value (mass based) of component “i” in MJ/kg, in accordance with Paragraph 12.6.1 of this Annex I.
Hm	=	gross heating value (mass based) of the LNG unloaded in MJ/kg, calculated in accordance with the method specified in Paragraph 12.3 of this Annex I, rounded to four (4) decimal places.
Hv	=	gross heating value (volume based) of the LNG unloaded in BTU/SCF, calculated in accordance with the method specified in Paragraph 12.5 of this Annex I.
K1	=	volume correction in m3/kmol, at temperature Tl, obtained by linear interpolation from Paragraph 12.6.3 of this Annex I, rounded to six (6) decimal places.

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K2	=	volume correction in m3/kmol, at temperature Tl obtained by linear interpolation from Paragraph 12.6.4 of this Annex I, rounded to six (6) decimal places.
Mi	=	molecular mass of component “i” in kg/kmol, in accordance with Paragraph 12.6.1 of this Annex I.
P	=	average absolute pressure of vapor in an LNG Vessel immediately before unloading, in millibars, rounded to a whole millibar.
Q	=	number of MMBTU contained in the LNG delivered, rounded to the nearest ten (10) MMBTU.
Tl	=	average temperature of the liquid cargo in the LNG Vessel immediately after unloading, in degrees Celsius, rounded to one (1) decimal place.
Tv	=	average temperature of the vapor in an LNG Vessel immediately before unloading, in degrees Celsius, rounded to one (1) decimal place.
V	=	the volume of the liquid cargo unloaded, in cubic meters, rounded to three (3) decimal places.
Vh	=	the volume of the liquid cargo in an LNG Vessel immediately after unloading, in cubic meters, rounded to three (3) decimal places.
Vb	=	the volume of the liquid cargo in an LNG Vessel immediately before unloading, in cubic meters, rounded to three (3) decimal places.
Vi	=	molar volume of component “i” at temperature Tl, in m3/kmol, obtained by linear interpolation from Paragraph 12.6.2 of this Annex I, rounded to six (6) decimal places.
Xi	=	molar fraction of component “i” of the LNG samples taken from the receiving line, rounded to four (4) decimal places, determined by gas chromatographic analysis.
Xm	=	the value of Xi for methane.
Xn	=	the value of Xi for nitrogen.

12.1 Density Calculation Formula

The density of the LNG unloaded which is used in the MMBTU calculation in 12.4 of this Annex I shall be calculated from the following formula derived from the revised Klosek-McKinley method:

In the application of the above formula, no intermediate rounding shall be made if the accuracy of “d” is thereby affected.

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12.2 Calculation of Volume Delivered

The volume, in cubic meters, of each LNG cargo unloaded shall be calculated by using the following formula:

12.3 Calculation of Gross Heating Value (Mass Based)

The gross heating value (mass based), in MJ/kg, of each LNG cargo unloaded shall be calculated by using the following formula:

12.4 MMBTU Calculation of the Quantity of LNG Unloaded

The number of MMBTU contained in the LNG unloaded shall be calculated using the following formula:

The derivation of the conversion factor 1/1055.12 in the formula in this Paragraph for the conversion of MJ into MMBTU is obtained from GPA-2145:1994 and IP-251:1976 as follows:

(a) q(T,P) means the gross heating value (measured at temperature T and pressure P), contained in a given quantity of gas;

(b) q(60°F, 14.696 psia) in MJ = 1/1.00006 x q(15°C, 1013.25 millibar) in MJ;

(c) 1 MMBTU corresponds to 1055.06 MJ;

(d) q(60°F, 14.696 psia) in MMBTU = 1/1055.06 x q(60°F, 14.696 psia) in MJ; and

(e) Combining (b) and (d) above yields:

q(60°F, 14.696 psia) in MMBTU = 1/1055.12 x q(15°C, 1013.25 millibar) in MJ.

Hence the number of MJ derived shall be divided by 1055.12 to obtain the number of MMBTU for invoicing purposes.

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12.5 Calculation of Gross Heating Value (Volume Based)

The calculation of the Gross Heating Value (Volume Based) in BTU/SCF shall be derived from the same compositional analysis as is used for the purposes of calculating the Gross Heating Value (Mass Based) Hm and the following formula shall apply:

The derivation of the conversion factor 1.13285 for the conversion of MJ/kmol into BTU/SCF is obtained as follows:

(a) molar gross heating value =

(b) 1 kmol = 2.20462 lbmol;

(c) 1 lbmol = 379.482 SCF;

(d) hence 1 kmol = 836.614 SCF; and

12.6 Data

(a) Values of Hi and Mi

Component	Hi (in MJ/kg)	Mi (in kg/kmol)
Methane	55.575	16.043
Ethane	51.950	30.070
Propane	50.368	44.097
Iso-Butane	49.388	58.123
N-Butane	49.546	58.123
Iso-Pentane	48.949	72.150
N-Pentane	49.045	72.150
N-Hexane	48.716	86.177
Nitrogen	0	28.013
Carbon Dioxide	0	44.010
Oxygen	0	31.999

Source: GPA Publication 2145 Sl-96: “Physical Constants of Paraffin Hydrocarbons and other components of natural gas”.

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(b) Values of Vi (cubic meter/kmol)

Temperature	-150°C	-154°C	-158°C	-160°C	-162°C	-166°C	-170°C
Methane	0.039579	0.038983	0.038419	0.038148	0.037884	0.037375	0.036890
Ethane	0.048805	0.048455	0.048111	0.047942	0.047774	0.047442	0.047116
Propane	0.063417	0.063045	0.062678	0.062497	0.062316	0.061957	0.061602
Iso-Butane	0.079374	0.078962	0.078554	0.078352	0.078151	0.077751	0.077356
N-Butane	0.077847	0.077456	0.077068	0.076876	0.076684	0.076303	0.075926
Iso-Pentane	0.092817	0.092377	0.091939	0.091721	0.091504	0.091071	0.090641
N-Pentane	0.092643	0.092217	0.091794	0.091583	0.091373	0.090953	0.090535
N-Hexane	0.106020	0.105570	0.105122	0.104899	0.104677	0.104236	0.103800
Nitrogen	0.055877	0.051921	0.048488	0.046995	0.045702	0.043543	0.041779
Carbon Diox	0.027950	0.027650	0.027300	0.027200	0.027000	0.026700	0.026400
Oxygen	0.03367	0.03275	0.03191	0.03151	0.03115	0.03045	0.02980

Source: National Bureau of Standards Interagency Report 77-867, Institute of Petroleum IP251/76 for Oxygen.

Note: For intermediate values of temperature and molecular mass a linear interpolation shall be applied

(c) Values of Volume Correction Factor, K1 (cubic meter/kmol)

Molecular Mass of Mixture	-150°C	-154°C	-158°C	-160°C	-162°C	-166°C	-170°C
16.0	-0.000012	-0.000010	-0.000009	-0.000009	-0.000008	-0.000007	-0.000007
16.5	0.000135	0.000118	0.000106	0.000100	0.000094	0.000086	0.000078
17.0	0.000282	0.000245	0.000221	0.000209	0.000197	0.000179	0.000163
17.2	0.000337	0.000293	0.000261	0.000248	0.000235	0.000214	0.000195
17.4	0.000392	0.000342	0.000301	0.000287	0.000274	0.000250	0.000228
17.6	0.000447	0.000390	0.000342	0.000327	0.000312	0.000286	0.000260
17.8	0.000502	0.000438	0.000382	0.000366	0.000351	0.000321	0.000293
18.0	0.000557	0.000486	0.000422	0.000405	0.000389	0.000357	0.000325
18.2	0.000597	0.000526	0.000460	0.000441	0.000423	0.000385	0.000349
18.4	0.000637	0.000566	0.000499	0.000477	0.000456	0.000412	0.000373
18.6	0.000677	0.000605	0.000537	0.000513	0.000489	0.000440	0.000397
18.8	0.000717	0.000645	0.000575	0.000548	0.000523	0.000467	0.000421
19.0	0.000757	0.000685	0.000613	0.000584	0.000556	0.000494	0.000445
19.2	0.000800	0.000724	0.000649	0.000619	0.000589	0.000526	0.000474
19.4	0.000844	0.000763	0.000685	0.000653	0.000622	0.000558	0.000503
19.6	0.000888	0.000803	0.000721	0.000688	0.000655	0.000590	0.000532
19.8	0.000932	0.000842	0.000757	0.000722	0.000688	0.000622	0.000561
20.0	0.000976	0.000881	0.000793	0.000757	0.000721	0.000654	0.000590
25.0	0.001782	0.001619	0.001475	0.001407	0.001339	0.001220	0.001116
30.0	0.002238	0.002043	0.001867	0.001790	0.001714	0.001567	0.001435

Source: National Bureau of Standards Interagency Report 77-867.

Note 1: Molecular mass of mixture equals .

Note 2: For intermediate values of temperature and molecular mass a linear interpolation shall be applied.

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(d) Values of Volume Correction Factor, K2 (cubic meter/kmol)

Molecular Mass of Mixture	-150°C	-154°C	-158°C	-160°C	-162°C	-166°C	-170°C
16.0	-0.000039	-0.000031	-0.000024	-0.000021	-0.000017	-0.000012	-0.000009
16.5	0.000315	0.000269	0.000196	0.000178	0.000162	0.000131	0.000101
17.0	0.000669	0.000568	0.000416	0.000377	0.000341	0.000274	0.000210
17.2	0.000745	0.000630	0.000478	0.000436	0.000397	0.000318	0.000246
17.4	0.000821	0.000692	0.000540	0.000495	0.000452	0.000362	0.000282
17.6	0.000897	0.000754	0.000602	0.000554	0.000508	0.000406	0.000318
17.8	0.000973	0.000816	0.000664	0.000613	0.000564	0.000449	0.000354
18.0	0.001049	0.000878	0.000726	0.000672	0.000620	0.000493	0.000390
18.2	0.001116	0.000939	0.000772	0.000714	0.000658	0.000530	0.000425
18.4	0.001184	0.001000	0.000819	0.000756	0.000696	0.000567	0.000460
18.6	0.001252	0.001061	0.000865	0.000799	0.000735	0.000605	0.000496
18.8	0.001320	0.001121	0.000912	0.000841	0.000773	0.000642	0.000531
19.0	0.001388	0.001182	0.000958	0.000883	0.000811	0.000679	0.000566
19.2	0.001434	0.001222	0.000998	0.000920	0.000844	0.000708	0.000594
19.4	0.001480	0.001262	0.001038	0.000956	0.000876	0.000737	0.000623
19.6	0.001526	0.001302	0.001078	0.000992	0.000908	0.000765	0.000652
19.8	0.001573	0.001342	0.001118	0.001029	0.000941	0.000794	0.000681
20.0	0.001619	0.001382	0.001158	0.001065	0.000973	0.000823	0.000709
25.0	0.002734	0.002374	0.002014	0.001893	0.001777	0.001562	0.001383
30.0	0.003723	0.003230	0.002806	0.002631	0.002459	0.002172	0.001934

Source: National Bureau of Standards Interagency Report 77-867.

Note 1: Molecular mass of mixture equals .

Note 2: For intermediate values of temperature and molecular mass a linear interpolation shall be applied.

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ANNEX II

MEASUREMENTS AND TESTS FOR GAS AT DELIVERY POINT

1. Applicability. The measurement procedures in this Annex II shall apply to the measurement of quantities (volume, energy) Gas delivered by SABINE for Customer’s Account at the Delivery Point.

2. Unit of Measurement. All Gas delivered at the Delivery Point shall be measured in MMBTU.

3. Metering.

(a) Metering Equipment. SABINE shall supply, operate and maintain (or cause to be supplied, operated and maintained at or near the Delivery Point) the following:

(i) meters with redundancy and other equipment as is necessary to accurately measure the volume of Gas delivered at the Delivery Point hereunder;

(ii) devices for collecting samples and for determining the quality and composition of Gas delivered at the Delivery Point hereunder; and

(iii) and any other measurement or testing devices which are necessary to perform the measurement and testing required hereunder at the Delivery Point.

(collectively, the “Downstream Metering Equipment”). The Downstream Metering Equipment shall be designed and installed in accordance with the current recommendations of the American Gas Association, Report No. 3 and 9 for Ultrasonic Metering.

(b) General. A pressure transmitter shall be installed on each meter tube to measure the static pressure at the plane of the upstream differential pressure tapping. The temperature of the flowing Gas shall be measured on each meter tube by a platinum resistance thermometer installed in a thermowell so that the probe tip is in the center one-third of the pipe. Each meter run shall be provided with a dedicated microprocessor-based flow computer system powered by an appropriate back-up power supply.

(c) Measuring and Density Standards. Gas shall be measured by ultrasonic meters. Ultrasonic meters shall be constructed and operated, Gas shall be measured, and properties shall be determined in accordance with American Gas Association, Report No. 9 and any subsequent modification and amendment thereof. The compressibility and density shall be calculated in accordance with the latest revision of the American Gas Association, Report No. 9. Metering equipment shall include the use of flow conditioners, straightening vanes, and pulsation dampening devices where necessary. Meter tubes shall be of a design

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incorporating suitable access for periodic internal inspection, including access for internal inspection of the upstream side of the flow conditioner. Electronic gas measurement with a continuous readout of pressure, temperature, and Gas flow rate shall be used. All computations shall be made as prescribed in the above cited standard.

(d) Ultrasonic Metering Standard. All ultrasonic metering shall comply with the American Gas Association, Report No. 9 and any subsequent modification and amendment thereof.

4. Determination of Gross Heating Value.

(a) GPA 2261 and 2145. The heating value of the Gas delivered by SABINE at the Delivery Point shall be determined by gas chromatograph. The composition of the Gas shall be continuously measured by on-line chromatographs. The Gross Heating Value of the Gas shall be calculated using results from the on-line chromatograph. The chromatographs will analyze all hydrocarbon components, up to and including at least the Nonanes+ group, and inerts having a concentration of greater than zero point zero zero two mole percent (0.002%). The determination of Gas composition shall be in accordance with the GPA Standard 2261 – Analysis for Natural Gas and Similar Gaseous Mixtures by Gas Chromatography. All physical properties used in quality and quantity calculations shall be based on these compositional analyses and the component values published in GPA 2145, or the latest revision thereof. Water vapor content shall be included in the component analyses. The sample analysis cycle time shall be less than six (6) minutes. The maximum response time from sample probe to analyzer shall be four (4) minutes. In the event of failure of the on-line Gas chromatograph, chromatograph analysis of samples collected proportional to the flow through the meters shall be used. Auto-calibration of the Gas chromatograph shall be conducted on a weekly basis or as otherwise mutually agreed by the Parties.

(b) GPA 2145. Back-up composite samples of the flowing Gas shall be obtained weekly to be used for relative density (specific gravity), Gross Heating Value, and compressibility factors in case of electronic failure. Composite sampling of the flowing stream shall be by use of a mutually agreeable continuous sampler, designed and installed to sample proportionally to the flow rate. The end point of each composite sample chromatographic analysis shall be the Nonane+ fraction, and values for this fraction shall be based on the C9 value in the latest revision of GPA Standard 2145 – Table of Physical Constants of Paraffin Hydrocarbons and Other Components of Natural Gas. All component values shall be in accordance with such standard.

(c) Quarterly Deviation Checks. Monthly gas chromatograph deviation checks shall be made on Gas composition mole percentages and resulting Gross Heating Value. Analyses of a sample of test Gas of known composition resulting when procedures that are in accordance with the above mentioned standards have been

2

applied will be considered as acceptable if the resulting calculated Gross Heating Value is within plus or minus five (5) BTU per Standard Cubic Foot of the known Gross Heating Value. If the deviation exceeds the tolerance stated, Gross Heating Value, relative density, and compressibility previously calculated will be corrected immediately. Previous analyses will be corrected to the point where the error occurred. If the point that the error occurred cannot be determined, previous analyses will be corrected for one-half the period since the last verification test, not to exceed a correction period of six (6) months.

(d) Corrections for Water Content. The heating value on a dry basis for Gas containing water shall be corrected in accordance with standards followed by the American Gas Association. Moisture content of flowing Gas shall be determined as often as found necessary in real practice by use of a mutually acceptable calculation or test instrument, which could include a Meco Moisture Analyzer.

5. Operating Procedures

(a) Notice. Prior to conducting operations for measurement, calibration, sampling and analysis provided in Annex II, the Party responsible for such operations shall notify the appropriate representatives of the other Party, allowing such representatives reasonable opportunity to be present for all operations and computations; provided that the absence of the other Party’s representative after notification and opportunity to attend shall not prevent any operations and computations from being performed.

(b) Independent Surveyor. At the request of either Party any measurement, calibration, sampling and analysis shall be witnessed and verified by an independent surveyor mutually agreed upon by Customer and SABINE. The results of such surveyor’s verifications shall be made available promptly to each Party.

(c) Preservation of Records. All records of measurement and the computed results shall be preserved by the Party responsible for taking the same, or causing the same to be taken, and made available to the other Party for a period of not less than three (3) years after such measurement and computation.

6. Verification. At least once each month, and in addition, from time to time upon at least two (2) weeks prior written notice by either Party to the other, SABINE shall verify or cause to be verified the accuracy of the Downstream Metering Equipment. When as a result of such test any of the Downstream Metering Equipment is found to be out of calibration within the accuracy provided by the manufacturer in the specification for such equipment, no adjustment shall be made to the Fee. If the testing of the Downstream Metering Equipment demonstrates that any meter is out of calibration by more than the accuracy provided by the manufacturer in the specifications for such equipment, the applicable Downstream Metering Equipment reading for the actual period during which out of calibration measurements were made shall be estimated as follows, in descending order of priority:

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(a) by using the registration of any check meter or meters if installed and accurately registering;

(b) by correcting the error if the percentage of error is ascertainable by calibration, test, or mathematical calculation; or

(c) by estimating the quantity of delivery by measuring deliveries during prior periods under similar conditions when any meter was registering accurately.

If the actual period that such equipment has been out of calibration cannot be determined to the mutual satisfaction of SABINE and Customer, the adjustment shall be for a period equal to one-half of the time elapsed since the most recent test. The previous payments made by Customer to SABINE for this period shall be subtracted from the amount of payments that are calculated to have been owed under this Agreement. The difference (which may be a positive or negative amount) shall be added to the next monthly statement pursuant to Section 11.2.

7. Costs. The cost of the monthly testing and calibration of the Downstream Metering Equipment shall be borne by SABINE. The cost of any testing and calibration of the Downstream Metering Equipment beyond the monthly test permitted above shall also be paid by SABINE, unless the request to test any of the Downstream Metering Equipment is made by Customer and the results of such test requested by Customer demonstrate that the Downstream Metering Equipment is less than one percent (1%) out of calibration or outside of the accuracy given by the manufacturer, in which case the cost of such testing and calibration shall be for Customer’s account. Each Party shall comply with any reasonable request of the other Party concerning the sealing of the Downstream Metering Equipment, the presence of a representative of Customer when the seals are broken and tests are conducted, and other matters affecting the accuracy, testing and calibration of the Downstream Metering Equipment.

8. Disputes. Any Dispute arising under this Annex II shall be submitted to an Expert under Section 20.2.

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EXHIBIT A

SABINE PASS SERVICES MANUAL

The Sabine Pass Services Manual referred to in Section 3.5 shall address the following matters and other matters of a similar nature:

1. Details associated with the implementation of Sections 5.1 and 5.2 among SABINE, Customer and Other Customers;

2. Details associated with the Gas delivery procedures in Section 5.3 among SABINE, Customer and Other Customers;

3. Details associated with the content and format of the Sabine Pass Website;

4. Details associated with the invoicing process under Article 11 including:

a. Format of invoices (electronic and original)

b. Numbering systems/codes for all invoice-related documents.

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EXHIBIT B

PORT LIABILITY AGREEMENT

THIS PORT LIABILITY AGREEMENT (this “Agreement”) is effective as of             , 20    , and is made by and between Sabine Pass LNG L.P., a Delaware limited partnership (“SABINE”), represented herein by Sabine Pass LNG-GP, Inc., its General Partner, and [INSERT NAME(S) OF VESSEL OWNER(S)], a [TYPE OF ENTITY AND JURISDICTION OF ORGANIZATION] (collectively “Vessel Owner”).

RECITALS

WHEREAS, Vessel Owner, using the LNG vessel set forth below under its name and signature (“Vessel”), proposes to deliver certain quantities of liquefied natural gas to SABINE at its marine terminal and receiving, storage and regasification facilities located on the Sabine River, Cameron Parish, Louisiana (as more fully defined below, the “Marine Terminal”); and

WHEREAS, Vessel Owner and SABINE (collectively, the “Parties” and individually a “Party”) have agreed to allocate the risk of and responsibility for loss and damage resulting from an Incident (as defined below) at the Marine Terminal in the following manner;

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows:

1. The following terms shall have the following meanings when used herein:

“Affiliate” means, with respect to any Person, any other Person which, directly or indirectly, controls, is controlled by, or is under common control with, such Person. For purposes of this definition, “control” (including, with correlative meanings, the terms “controlled by” and “under common control with”) means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a Person, whether through the ownership of voting securities or otherwise.

“Incident” means any occurrence or series of occurrences having the same origin arising out of or relating to the Vessel’s use of the Marine Terminal in which there is any one or more of the following: (i) loss of or damage to the Marine Terminal or the Vessel; (ii) injury to the employees and agents comprising Terminal Interests or Vessel Interests; (iii) loss or damage, other than to the Marine Terminal or the Vessel, caused or contributed to by the Vessel, including but not limited to, injury to third parties or damage to the property of third parties; or (iv) an obstruction or danger affecting or interfering with the normal operation of the Marine Terminal or the Port.

“Terminal Interests” means: (i) SABINE; (ii) all Affiliates of SABINE; (iii) all Persons (other than the Vessel Interests and Persons providing fire boats, tugs and escort vessels to Vessel at the Port) employed or providing services at the Marine Terminal in connection with the unloading, storage, or regasification of LNG at the Marine Terminal; and (iv) the employees and agents of all Persons referred to in this paragraph.

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“Marine Terminal” means SABINE’s marine terminal and LNG receiving, storage and regasification facilities located at the Port, including all berths, buoys, gear, craft, equipment, plant, facilities and property of any kind (whether afloat or ashore) located thereat or adjacent thereto and in the ownership, possession or control of the Terminal Interests.

“Person” means any individual, firm, corporation, trust, partnership, association, joint venture (incorporated or unincorporated), or other business entity.

“Port” means the port at or near the mouth of the Sabine River, Cameron Parish, Louisiana, including its anchorage, turning basin and approaches into the Marine Terminal associated therewith.

“Vessel Interests” means: (i) Vessel Owner; (ii) all Affiliates participating in the ownership and/or operation of Vessel; (iii) all Persons (other than the Terminal Interests) participating, employed, or providing services in connection with the ownership or operation (including all operations related to navigation and berthing/unberthing) of the Vessel; and (iv) the employees and agents of all Persons referred to in this paragraph.

2. In all circumstances, the master of the Vessel shall remain solely responsible on behalf of the Vessel Interests for the proper navigation and safety of the Vessel and her cargo.

3. Any liability arising from an Incident shall, as between the Vessel Interests and the Terminal Interests, be borne: (i) by the Vessel Interests alone, if the Vessel Interests are wholly or partially at fault and the Terminal Interests are not at fault; (ii) by the Terminal Interests alone, if the Terminal Interests are wholly or partially at fault and the Vessel Interests are not at fault; (iii) by the Vessel Interests and the Terminal Interests, in proportion to the degree of their respective fault, if both are at fault and the degree of such fault can be established; or (iv) by the Vessel Interests and the Terminal Interests equally if neither of them appears to be at fault or it is not possible to establish the degree of their respective fault. In this regard, any acts or omissions of Persons providing fire boats, tugs and escort vessels to Vessel at the Port shall be deemed to be the responsibility of the Vessel Interests.

4.

(i) SABINE shall be solely responsible for claims brought by any employee and/or member of the family or dependent of any employee of SABINE arising out of or consequent upon the personal injury, loss or damage to property of, or death of such employee, family member or dependent, and SABINE shall indemnify and hold any Vessel Owner harmless in the event any such employee, or any family member or dependent thereof, or the executor, administrator, or personal representative of any of the foregoing, shall bring such a claim against any Vessel Owner.

(ii) The Vessel Owners shall be solely responsible for claims brought by any employee and/or member of the family or dependent of any employee of any Vessel Owner arising out of or consequent upon the personal injury, loss or

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damage to property of, or death of such employee, family member or dependent, and each Vessel Owner shall indemnify and hold SABINE harmless in the event any such employee, or any family member or dependent thereof, or the executor, administrator or personal representative of any of the foregoing, shall bring such claim against SABINE.

(iii) SABINE and the Vessel Owners shall consult together to the extent practicable before either makes any payment which would fall due to be indemnified by the other under the terms of Sections 4(i) or 4(ii). The indemnities contained in Sections 4(i) and 4(ii) are separate and distinct from, and independent of, the obligations undertaken and the responsibilities and exceptions from and the limitations of liability provided in Sections 2, 3, 5 and 6 of this Agreement.

(iv) The cross indemnities provided in this Section 4 are intended to be binding regardless of fault or negligence on the part of the party in whose favor they are being given.

5.

(i) Subject to Section 5(ii) below, the total aggregate liability of the Vessel Interests to the Terminal Interests, however arising, in respect of any one Incident, shall not exceed one hundred fifty million U.S. dollars ($150,000,000). Payment of an aggregate sum of one hundred fifty million U.S. dollars ($150,000,000) to any one or more of the Terminal Interests in respect of any one Incident shall be a complete defense to any claim, suit or demand relating to such Incident made by the Terminal Interests against the Vessel Interests. The liability of the Vessel Interests hereunder shall be joint and several.

(ii) Vessel Interests shall provide to the Terminal Interests at all times sufficient written evidence that the Vessel’s Protection and Indemnity Association has agreed to: (a) cover the Vessel Interests as a member of the Association against the liabilities and responsibilities provided for in this Agreement in accordance with its Rules; (b) give the Terminal Interests prior notice of cancellation of the Vessel’s entry in such Protection and Indemnity Association; and (c) waive in favor of the Terminal Interests all rights of subrogation of claims by the Protection and Indemnity Association against the Terminal Interests to the extent such claims have been waived in this Agreement by the Vessel Interests.

6. As to matters subject to this Agreement and regardless of fault or negligence on the part of any Party, with respect to an Incident:

(i) except to the extent expressly preserved in this Agreement, Terminal Interests hereby expressly, voluntarily and intentionally waive any right or claims they might otherwise have against the Vessel Interests under applicable laws or under any port liability agreement or similar port conditions of use previously signed by the Master for the Port; and

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(ii) except to the extent expressly preserved in this Agreement, Vessel Interests hereby expressly, voluntarily and intentionally waive any rights to limit their liability under the United States Limitation of Vessel Owners Liability Act or any other similar law or convention, as applicable. Such waiver shall include any right to petition a court, arbitral tribunal or other entity for limitation of liability, any right to claim limitation of liability as a defense in an action, and any other similar right under relevant law. The foregoing waivers shall apply to all Persons claiming through the Terminal Interests or through the Vessel Interests.

7. The substantive law of New York, without regard to any conflicts of law principles that could require the application of any other law, shall govern the interpretation of this Agreement and any dispute, controversy, or claim arising out of, relating to, or in any way connected with this Agreement, including, without limitation, the existence, validity, performance, or breach hereof.

8. If and for so long as any provision of this Agreement shall be deemed to be judged invalid for any reason whatsoever, such invalidity shall not affect the validity or operation of any other provision of this Agreement except only so far as shall be necessary to give effect to the construction of such invalidity, and any such invalid provision shall be deemed severed from this Agreement without affecting the validity of the balance of this Agreement.

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their duly authorized representatives effective as of the date first set forth above.

SABINE PASS LNG L.P.		[INSERT SIGNATURES OF EACH OF VESSEL OWNERS]
By:	SABINE PASS LNG-GP, as General Partner
By:		By:
Title:		Title:
		As owner of the [Name of Vessel] Registration No. [                        ] State of Registry [                        ]

B-4

C-1

EX-10.7

Exhibit 10.7

MASTER LOAN AGREEMENT

Dated as of May 8, 2007

Between

Cheniere LNG Services, Inc., registered under the laws of Delaware, United States of America, having its permanent place of business at 717 Texas Avenue, Suite 3100, Houston, Texas 77002, United States of America, hereinafter referred to as the Lender, represented by the directors, on the one hand.

And

J & S Cheniere SA, registered under the laws of Switzerland, having its permanent place of business at 9 Route de St-Cergue, CH – 1260 Nyon, Switzerland hereinafter referred to as the Borrower, represented by the directors, on the other hand.

Whereas:

The Lender has agreed to advance to the Borrower by way of loan(s) the sum(s) specified in Addendum(s) attached to this Master Loan Agreement (“Agreement”) and referred to as the capital sum;

The funds shall be used for the financing of Borrower’s business operations;

The Lender has entered into this Agreement at the request of the Borrower; and

The parties now wish to record in writing the terms and conditions of any loan(s) made under this Agreement which will form the general terms and understanding of any loan(s) designated and identified in any Addendum(s) to this Agreement.

Now this Agreement witnessed and agreed by and between the parties hereto as follows:

1. Interpretation

In the construction of this Agreement and except to the extent that such construction shall be excluded by or shall be repugnant to the context:

“Borrower” means J & S Cheniere SA and includes where the context so admits each one and all of them and its or their respective successors, executors, administrators and assigns jointly and severally;

“Lender” means Cheniere LNG Services, Inc. and includes where the context so demands each one and all of them and its successors, executors, administrators and assigns jointly and severally;

The “capital sum” means an amount of US Dollars that are identified in an Addendum to this Agreement;

“Notice” means a written notice sent by one party to the other party at the address specified above, Attention: Treasurer. The address for Notice of any party may be changed upon Notice to the other party;

The singular numbers shall mean and include the plural numbers and vice versa and reference to one gender shall include a reference to all other genders;

Reference to persons shall include forms, corporations and any other entity recognised by law.

2. Loan

The Lender hereby lends to the Borrower who hereby borrows the amount of the capital sum as may be specified in any Addendum executed by the parties and attached to this Agreement.

The Lender will advance the capital sum to the Borrower on the date set forth in the applicable Addendum attached to this Agreement. All Addenda shall be in a format substantially similar to that of Addendum 001 attached to this Agreement.

The capital sum together with the interest accrued will be repayable at the latest on the date set forth to the applicable Addendum attached to this Agreement. This period can be extended my mutual written agreement between the Lender and the Borrower.

3. Repayment and Term

The loan expires on the date specified in the applicable Addendum attached to this Agreement. The Borrower shall make payments of the capital sum and interest upon expiration of the term or as may otherwise be specified in any Addendum.

4. Interest

The interest rate applicable to the loan shall be the lesser of: (i) the six (6) months USD-LIBOR (as quoted on page 3750 of the Dow Jones Markets (Telerate) Service (or any successor)) on the funding date of the loan under each Addendum and each six (6) months thereafter at 11:00 a.m. CET) plus one percent (1.0%) per annum, simple interest, calculated on an actual 360 day basis; and (ii) the maximum effective rate authorized, from time to time, by the Swiss taxing authority, for J&S Cheniere shareholder loans.

The Borrower shall, in accordance with the terms of any Addendum executed by the parties, transfer to the Lender the capital sum and the amount of interest which will accrue, by bank transfer.

5. Prepayment

The Loan may be prepaid in whole or in part, at any time, without penalty, upon 30 day’s prior written notice by the Borrower to the Lender.

6. Representation and Warranties

The Borrower represents and warrants to the Lender, as of the date of this Agreement or any subsequent Addendum to this Agreement, that no litigation or claim, including unpaid taxes against the Borrower, is pending or threatened and no other event has occurred which may adversely affect the Borrower’s financial condition other than such litigation, claim or other event, if any, that has been disclosed in writing to the Lender.

7. Waiver

Neither failure to exercise nor any delay in exercising on the part of the Lender any right shall operate as a waiver thereof, nor shall any single or partial exercise of any right prevent any further or other exercise thereof of any other right. The rights herein provided are not exclusive of any other rights provided by law.

8. General

8.1 Governing law: This Agreement shall be interpreted, governed by, and construed in accordance with Swiss law.

8.2 Exclusive jurisdiction: All disputes between the parties relating to this Agreement, regardless of whether they relate to the creation, validity, performance, implementation, interpretation or termination of, or the legal relationships established by this Agreement, or otherwise arising in connection with this Agreement, shall be submitted to the exclusive jurisdiction of the Swiss courts in the Canton of Vaud.

8.3 Headings: The headings and section references in this Agreement are for convenience of reference only and do not form a part of this Agreement and are not intended to interpret, define or limit the scope, extent or intent of this Agreement or any prevision hereunder.

8.4 Binding effect: This Agreement shall be binding upon the Borrower and its successors and assigns and shall insure to the benefit of, and be enforceable by the Lender, and its successors and assigns. This Agreement may not be assigned and/or transferred by either party hereto without the prior express written consent of the other party.

8.5 Amendment: This instrument constitutes the entire Agreement between the parties hereto relating to the subject matter hereof and may not be amended, waived or discharged except by written instrument duly executed by the parties hereto. Any and all previous agreements and understandings between the parties regarding the subject matter hereof, whether written or oral, are cancelled and superseded by this Agreement.

8.6 Further assurances: Each of the parties hereto covenants and agrees to execute such further and other documents and instruments and do such further acts and other things as it may be necessary to implement and carry out the intent of this Agreement.

8.7 Severability: In the event that any one or more of the provisions of this Agreement shall, for any reason, be held invalid, illegal or unenforceable in any respect by a person or a body of competent jurisdiction, the parties agree that such person or body may interpret this Agreement without reference to such invalid, illegal or unenforceable provision; provided, however, that wherever possible such person or body shall modify or restrict the meaning of such provision so that, as modified, it shall be enforceable.

8.8 Borrower expense: All of the expenses, rights and fees in relation with this Agreement shall be borne by the Borrower.

In witness whereof, the parties hereto have duly executed this Agreement.

The Borrower		The Lender
J & S Cheniere S.A.		Cheniere LNG Services, Inc.
By:	/s/ Marco Dunand	By:	/s/ Graham McArthur
			Graham McArthur
Director			Treasurer
By:	/s/ Alain Rappo	By:	/s/ Craig K. Townsend
			Craig K. Townsend
Director			Attorney-in-Fact

ADDENDUM 001

This Addendum (this “Addendum”) is entered into this the 8th day of May, 2007 by and between Cheniere LNG Services, Inc., Houston, Texas, United States of America (“Lender”) and J & S Cheniere S.A. Nyon, Switzerland (“Borrower”) pursuant to a certain Master Loan Agreement (“Agreement”) dated the date hereof between the parties.

Whereas:

Borrower has entered into: (i) LNG Carrier Time Charter Party Agreement, dated, as of August 25, 2004 with “K” Line LNG Transport Co., Ltd.; and (ii) LNG Carrier Time Charter Party Agreement, dated, as of August 26, 2004 with Trinity LNG Transport S.A., (collectively, the “Charter Party Agreements” and individually, a “Charter Party Agreement”).

The Lender has entered into a certain Amended and Restated Shareholders Agreement dated the date hereof (“Shareholders Agreement”), with Mercuria Energy Holdings B.V., Utrecht, Netherlands (“Mercuria”) which provides in paragraph 2.3(b)(i) thereof that Lender has agreed to advance to Borrower the below capital sum to collateralize certain obligations of Borrower under the Charter Party Agreements.

In furtherance of the foregoing undertaking contained in the Shareholders Agreement, the Lender and Borrower have entered into the Agreement which provides in part that any loans made by Lender to Borrower shall be recorded and documented by use of this Addendum.

As Borrower desires to borrow funds from Lender and Lender agrees to loan such funds in accordance with the terms of the Shareholders Agreement, the Agreement and this Addendum.

Now therefore, Lender and Borrower agree to document this loan under the following supplemental terms to the Agreement:

1. Loan

The Lender hereby lends to the Borrower who hereby borrows the amount of US Dollars 25 million ($25,000,000) (the “capital sum”).

The Lender will advance the capital sum to the Borrower within seven (7) business days of the date hereof (the “funding date”).

The capital sum together with the interest accrued will be repaid as follows:

1. one-half of the capital sum (US dollars 12.5 million) will be repaid to Lender with interest accrued within five (5) business days of the expiration or termination of the Charter Party Agreement whose term first expires or is otherwise terminated, and

2. the remainder of the capital sum unpaid will be repaid to Lender with interest accrued within five (5) business days of the expiration or termination of the next Charter Party Agreement whose term subsequently expires or is otherwise terminated.

For purposes of the foregoing two clauses, the term “termination” shall include the termination of any Charter Party Agreement whether through voluntary act of the parties thereto or through the occurrence of a default and subsequent termination under the applicable Charter Party Agreement.

Notwithstanding the foregoing, in the event Lender disposes of its stock in Borrower pursuant to the provisions of paragraphs 3.2 or 4.1 of the Shareholders Agreement, the full amount of the capital sum or any portion thereof remaining outstanding, with accrued interest, shall be repaid to the Lender, on or before the date of the actual transfer of the shares of stock of Borrower, in accordance with the provisions of paragraph 3.2(d) of the Shareholders Agreement.

2. Repayment and Term

Portions of the loan expire on the respective dates specified in Section 1 of this Addendum. The Borrower shall make payments of the portion of the capital sum and interest in accordance with Section 1 by wire transfer to an account specified in a Notice from Lender to Borrower.

3. Interest

Interest shall accrue and be charged and calculated in accordance with the terms of the Agreement.

4. Proceeds

Borrower represents and warrants to Lender that the proceeds of the loan obtained under this Addendum shall only be used to collateralize the obligations of the Borrower under and in accordance with the terms of the Charter Party Agreements.

The Lender and Borrower both acknowledge and agree that the terms of this Addendum shall be considered a part of and incorporated into the Agreement and that in the event a term in this Addendum is in conflict with the Agreement, the terms of this Addendum shall govern. All other terms and conditions (including, without limitation, the choice of law and the jurisdiction provisions) of the Agreement shall remain unchanged and binding on the parties and this Addendum.

In witness whereof, the parties hereto have duly executed this Addendum.

The Borrower		The Lender
J & S Cheniere S.A.		Cheniere LNG Services, Inc.
By:	/s/ Marco Dunand	By:	/s/ Graham McArthur
			Graham McArthur
Director			Treasurer
By:	/s/ Alain Ruppo	By:	/s/ Craig K. Townsend
			Craig K. Townsend
Director			Attorney-in-Fact

EX-10.8

Exhibit 10.8

May 8, 2007

Sabine Pass LNG, L.P.

717 Texas Avenue

Suite 3100

Houston, Texas 77002

Attention: President

Re: Potential TUA between J & S Cheniere S.A. (“J & S Cheniere”) and Sabine Pass

LNG, L.P. (“Sabine Pass”)

Gentlemen:

This letter confirms our agreement with regard to the potential terminal use agreement, or TUA, between J & S Cheniere and Sabine Pass involving the Sabine Pass LNG receiving terminal currently under construction in Cameron Parish, Louisiana.

1. The Amended and Restated Shareholders Agreement dated May 8, 2007 between Mercuria Energy Holding B.V. and Cheniere LNG Services, Inc. acknowledges that Cheniere Marketing, Inc. (“Cheniere Marketing”) and J & S Cheniere are negotiating and propose to enter into an LNG sale and purchase agreement that would provide for the sale by J & S Cheniere of approximately 78,475,000 mmbtu of stipulated maximum annual LNG reception quantity to Cheniere Marketing for delivery at the Sabine Pass LNG receiving terminal. The terms of such purchase agreement have not been finalized, and any definitive sale and purchase agreement that is entered into may involve substantially different terms. It is anticipated that such a sale and purchase agreement will provide for J & S Cheniere and Sabine Pass to enter into, in place of the sale and purchase agreement under certain circumstances, a TUA covering approximately 78,475,000 mmbtu of stipulated maximum annual LNG reception quantity at the Sabine Pass LNG receiving terminal, so long as the Sabine Pass LNG receiving terminal has commenced commercial operation.

2. The parties hereto agree to continue to negotiate in good faith the different terms under discussion involving such TUA. To the extent required pursuant to any definitive sale and purchase agreement between Cheniere Marketing and J & S Cheniere, Cheniere Marketing agrees to make available and/or relinquish 78,475,000 mmbtu of stipulated maximum annual LNG reception quantity under its terminal use agreement with Sabine Pass to satisfy any TUA entered between J & S Cheniere and Sabine Pass.

3. If the sale and purchase referred to in paragraph 1 above is implemented with a contemplated, although contingent, TUA between J & S Cheniere and Sabine Pass, then Sabine Pass agrees to execute and deliver such TUA in the form attached to the Amended and Restated Shareholders Agreement referenced in paragraph 1, with such changes as are reasonably acceptable to Sabine Pass.

4. This letter agreement terminates and supersedes the letter agreement dated November 9, 2006 among Sabine Pass, Cheniere Marketing and Cheniere LNG, Inc. (the “2006 Letter Agreement”).

If the foregoing correctly reflects our understanding, kindly execute in the space provided below and this letter shall evidence our agreement as to the matters set forth herein.

Sincerely,
Cheniere Marketing, Inc.
By:	/s/ Pat Yeater
Name:	Pat Yeater
Title:	V.P. Transportation

AGREED AS OF THE DATE FIRST ABOVE WRITTEN:
Sabine Pass LNG, L.P.
By:	Sabine Pass LNG – GP, Inc.,     its General Partner
By:	/s/ Keith Little
Name:	Keith Little
Title:	President

AGREED AS TO TERMINATION OF THE 2006 LETTER AGREEMENT EFFECTIVE AS OF THE DATE FIRST ABOVE WRITTEN:
Cheniere LNG, Inc.
By:	/s/ Graham McArthur
Name:	Graham McArthur
Title:	Treasurer

2

EX-31.1

EXHIBIT 31.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER PURSUANT TO

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

I, Charif Souki, certify that:

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

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

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

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

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

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

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

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

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

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

Date: May 8, 2007

/s/ Charif Souki

Charif Souki

Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

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

I, Don A. Turkleson, certify that:

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

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

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

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

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

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

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

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

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

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

Date: May 8, 2007

/s/ Don A. Turkleson

Don A. Turkleson

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

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

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the period ending March 31, 2007 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Charif Souki, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

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

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

/s/ Charif Souki

Charif Souki

Chief Executive Officer

May 8, 2007

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 ending March 31, 2007 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Don A. Turkleson, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

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

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

/s/ Don A. Turkleson

Don A. Turkleson

Chief Financial Officer

May 8, 2007