UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 10-K
 
x
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934
 
  For the fiscal year ended December 31, 2009
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. 001-33366
 
 
CHENIERE ENERGY PARTNERS, L.P.
 
 
(Exact name of registrant as specified in its charter)
   
Delaware
20-5913059
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
   
700 Milam Street, Suite 800
  
Houston, Texas
77002
(Address of principal executive offices)
(Zip code)
 
Registrant’s telephone number, including area code: (713) 375-5000
 
Securities registered pursuant to Section 12(b) of the Act:
 
   
Common Units Representing Limited
Partner Interests
NYSE Amex Equities
(Title of Class)
(Name of each exchange on which registered)
 
Securities registered pursuant to Section 12(g) of the Act: None
 
 
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes ¨    No x
 
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.    Yes ¨    No x
 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes x    No ¨
 
  Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes ¨   No ¨
 
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  x
 
 Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):
 
       
Large accelerated filer  ¨
Accelerated filer  x
Non-accelerated filer  ¨
Smaller reporting company  ¨
(Do not check if a smaller reporting company)
    
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x
 
The aggregate market value of the registrant’s Common Units held by non-affiliates of the registrant was approximately $192,000,000 as of June 30, 2009.
 
The issuer had 26,416,357 common units and 135,383,831 subordinated units outstanding as of February 17, 2010.
 
Documents incorporated by reference: None  
 

 
 
 

CHENIERE ENERGY PARTNERS, L.P
Index to Form 10-K
 
1 
1 
1 
1 
1 
2 
4 
4 
5 
5 
7 
13 
16 
20 
23 
23 
23 
23 
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26 
27 
27 
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28 
28 
34 
34 
36 
36 
37 
38 
39 
62 
62 
62 
63 
63 
66 
68 
70 
71 
72 
72 


i
 
 
 

CAUTIONARY STATEMENT
REGARDING FORWARD-LOOKING STATEMENTS
 
This annual 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 facts, included herein or incorporated herein by reference are “forward-looking statements.” Included among “forward-looking statements” are, among other things:
 
 
•
statements regarding our ability to pay distributions to our unitholders;
 
 
•
our expected receipt of cash distributions from Sabine Pass LNG, L.P.;
 
 
•
statements regarding future levels of domestic natural gas production, supply or consumption; future levels of LNG imports into North America; sales of natural gas in North America; and the transportation, other infrastructure or prices related to natural gas, LNG or other energy sources;
 
 
•
statements regarding any financing transactions or arrangements, or ability to enter into such transactions or arrangements;
 
 
•
statements regarding any terminal use agreement (“TUA”) or other agreements 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 LNG regasification or storage 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 legislative, governmental, regulatory, administrative or other public body actions, requirements, permits, investigations, proceedings or decisions; 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,” “develop,” “estimate,” “expect,” “forecast,” “plan,” “potential,” “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 annual report.
 
Our actual results could differ materially from those anticipated in these forward-looking statements as a result of a variety of factors, including those discussed in “Risk Factors.” 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 annual report.
 

ii
 
 
 
 
DEFINITIONS
 
In this annual report, unless the context otherwise requires:
 
 
 
•
Bcf means billion cubic feet;
 
 
•
Bcf/d means billion cubic feet per day;
 
 
•
EPC means engineering, procurement and construction;
 
 
•
EPCM means engineering, procurement, construction and management;
 
 
•
LNG means liquefied natural gas; and
 
 
•
TUA means terminal use agreement.
 
PART I
 
ITEMS 1. AND 2. BUSINESS AND PROPERTIES
General
 
We are a Delaware limited partnership formed by Cheniere Energy, Inc. (“Cheniere”). Through our wholly-owned subsidiary, Sabine Pass LNG, L.P. (“Sabine Pass LNG”), we own and operate the Sabine Pass LNG receiving terminal located in western Cameron Parish, Louisiana on the Sabine Pass Channel.
 
In March and April 2007, we and Cheniere LNG Holdings, LLC (“Holdings”), a wholly-owned subsidiary of Cheniere, as a selling untiholder, completed a public offering of 15,525,000 of our common units (the “Offering”). We received $98.4 million of net proceeds, after deducting the underwriting discount and structuring fees, upon issuance of 5,054,164 common units to the public in the Offering. We invested the $98.4 million of net proceeds that we received from the Offering in U.S. Treasury securities to fund a distribution reserve. As part of the Offering, Holdings, as a selling unitholder, received $203.9 million of net proceeds in connection with the sale of 10,470,836 of our common units to the public. We did not receive any proceeds from the sale of common units by Holdings. In connection with the Offering and in exchange for our common and subordinated units and the right to receive the amount, if any, remaining in a distribution reserve account, Holdings contributed to us the equity interests in the entity owning the Sabine Pass LNG receiving terminal. As a result of the Offering, Cheniere’s indirect ownership interest in us is approximately 90.6%.
 
In the second quarter of 2009, Sabine Pass LNG purchased Sabine Pass Tug Services, LLC (“Tug Services”), a wholly-owned subsidiary of Cheniere.  As a result, Sabine Pass LNG acquired a lease for the use of tug boats and marine services at the Sabine Pass LNG receiving terminal.  In connection with the acquisition, Tug Services entered into agreements with Sabine Pass LNG’s three TUA customers to provide their LNG cargo vessels with tug boat and marine services at the Sabine Pass LNG receiving terminal.
 
Overview of the LNG Industry
 
LNG is natural gas that, through a refrigeration process, has been reduced to a liquid state, which represents approximately 1/600th of its gaseous volume. The liquefaction of natural gas into LNG allows it to be shipped economically from areas of the world where natural gas is abundant and inexpensive to produce to other areas where natural gas demand and infrastructure exist to justify economically the use of LNG. LNG is transported using oceangoing LNG vessels specifically constructed for this purpose. LNG receiving terminals offload LNG from LNG vessels, store the LNG prior to processing, heat the LNG to return it to a gaseous state and deliver the resulting natural gas into pipelines for transportation to market.
 
Our Business Strategy
 
Our primary business objectives are to operate the Sabine Pass LNG receiving terminal and to generate stable cash flows sufficient to pay the initial quarterly distribution to our unitholders and, over time and upon satisfaction of these objectives, to increase our quarterly cash distribution. We intend to achieve these objectives by executing the following strategies:
 
 
•
successfully managing the operation of the Sabine Pass LNG receiving terminal; and
 
 
•
expanding our existing asset base through acquisitions from Cheniere or third parties, or our own development, of complementary businesses or assets, such as other LNG receiving terminals, natural gas storage assets and pipelines.

 
1
 
Our Business
 
Sabine Pass LNG has constructed and is now operating the Sabine Pass LNG receiving terminal in western Cameron Parish, Louisiana, on the Sabine Pass Channel. In 2003, Cheniere formed Sabine Pass LNG to own, develop and operate the Sabine Pass LNG receiving terminal.  Sabine Pass LNG has long-term leases for three tracts of land consisting of 853 acres in Cameron Parish, Louisiana for the project site.  The Sabine Pass LNG receiving terminal was designed, and permitted by the Federal Energy Regulatory Commission (“FERC”), with a regasification capacity of approximately 4.0 Bcf/d (with peak capacity of 4.3 Bcf/d) and aggregate LNG storage capacity of 16.9 Bcf. Construction at the Sabine Pass LNG receiving terminal was substantially completed in the third quarter of 2009.  As of December 31, 2009, Sabine Pass LNG had completed construction and attained full operability of the Sabine Pass LNG receiving terminal, and such was accomplished within our budget.

Customers
 
The entire approximately 4.0 Bcf/d of regasification capacity at the Sabine Pass LNG receiving terminal has been contracted under two 20-year, firm commitment TUAs with unaffiliated third parties, and a third TUA with Cheniere Marketing, LLC (“Cheniere Marketing”), a wholly-owned subsidiary of Cheniere.  Each of the three customers at the Sabine Pass LNG receiving terminal must make the full contracted amount of capacity reservation fee payments under its TUA whether or not it uses any of its reserved capacity.  Capacity reservation fee TUA payments will be made by the Sabine Pass LNG third-party customers as follows:
 
 
•
Total Gas and Power North America, Inc. (formerly known as Total LNG USA, Inc.) (“Total”) has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly capacity payments to Sabine Pass LNG aggregating approximately $125 million per year for 20 years that commenced on April 1, 2009.  Total, S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions; and
 
 
•
Chevron U.S.A., Inc. (“Chevron”) has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly capacity payments to Sabine Pass LNG aggregating approximately $125 million per year for 20 years that commenced on July 1, 2009.  Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.
 
In addition, Cheniere Marketing has reserved the remaining 2.0 Bcf/d of regasification capacity and is entitled to use any capacity not utilized by Total and Chevron.  Cheniere Marketing began making its TUA capacity reservation fee payments in the fourth quarter of 2008.  Cheniere Marketing is required to make monthly capacity payments aggregating approximately $250 million per year for the period from January 1, 2009 through at least September 30, 2028. Cheniere Marketing has a limited operating history, limited capital and no credit rating. Cheniere, which has guaranteed the obligations of Cheniere Marketing under its TUA, has a non-investment grade corporate rating.
 
Under each of these TUAs, Sabine Pass LNG is also entitled to retain 2% of the LNG delivered for the customer’s account, which Sabine Pass LNG will use primarily as fuel for revaporization and self-generated power at the Sabine Pass LNG receiving terminal.
 
Each of Total and Chevron has paid us $20.0 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 reservation fees payable under its TUA.
 
Competition
 
Sabine Pass LNG currently does not experience competition for its LNG terminal capacity because the entire approximately 4.0 Bcf/d of regasification capacity that is available at the Sabine Pass LNG receiving terminal has been fully reserved under three 20-year TUAs, under which each of the terminal’s customers is generally required to pay monthly fixed capacity reservation fees whether or not it uses any of its reserved capacity.
 
If and when Sabine Pass LNG has to replace any TUAs, we will compete with North American LNG receiving terminals and their customers. In addition, to the extent we are required to obtain LNG for cool down of the Sabine Pass LNG receiving terminal, Sabine Pass LNG must compete in the world LNG market to purchase and transport cargoes of LNG. Sabine Pass LNG may purchase and transport such cargoes at costs that may result in losses upon resale of the regasified LNG.
 
Governmental Regulation
 
The Sabine Pass LNG receiving terminal operations are subject to extensive regulation under federal, state and local statutes, rules, regulations and laws. These laws require that we engage in consultations with appropriate federal and state agencies and that we

 
2
 

obtain and maintain applicable permits and other authorizations. This regulatory burden increases the cost of operating the Sabine Pass LNG receiving terminal, and failure to comply with such laws could result in substantial penalties.  We have been in substantial compliance with all regulations discussed herein.
 
FERC
 
In order to site and construct the Sabine Pass LNG receiving terminal, we received and are required to maintain authorization from the FERC under Section 3 of the Natural Gas Act of 1938 (“NGA”). In addition, orders from the FERC authorizing construction of an LNG receiving terminal are typically subject to specified conditions that must be satisfied throughout operation of the Sabine Pass LNG receiving terminal. Throughout the life of the Sabine Pass LNG receiving terminal, we will be subject to regular reporting requirements to the FERC and the U.S. Department of Transportation regarding the operation and maintenance of the facilities.
 
In 2005, the Energy Policy Act of 2005 (“EPAct”) was signed into law. The EPAct gave the FERC exclusive authority to approve or deny an application for the siting, construction, expansion or operation of an LNG receiving terminal. The EPAct amended the NGA to prohibit market manipulation.  The EPAct increased civil and criminal penalties for any violations of the NGA, the Natural Gas Policy Act of 1978 (“NGPA”) and any rules, regulations or orders of the FERC up to $1.0 million per day per violation. In accordance with the EPAct, the FERC issued a final rule making it unlawful for any entity, in connection with the purchase or sale of natural gas or transportation service subject to the FERC’s jurisdiction, to defraud, make an untrue statement or omit a material fact or engage in any practice, act or course of business that operates or would operate as a fraud.
 
Other Federal Governmental Permits, Approvals and Consultations
 
In addition to the FERC authorization under Section 3 of the NGA, the operation of the Sabine Pass LNG receiving terminal is also subject to additional federal permits, approvals and consultations required by other federal agencies, including: Advisory Counsel on Historic Preservation, U.S. Army Corps of Engineers, U.S. Department of Commerce, National Marine Fisheries Services, U.S. Department of the Interior, U.S. Fish and Wildlife Service, U.S. Environmental Protection Agency (“EPA”) and U.S. Department of Homeland Security.
 
The Sabine Pass LNG receiving terminal is subject to U.S. Department of Transportation siting requirements and regulations of the U.S. Coast Guard relating to facility security. Moreover, the Sabine Pass LNG receiving terminal is subject to local and state laws, rules, and regulations.
 
Environmental Regulation
 
The Sabine Pass LNG receiving terminal operations are subject to various federal, state and local laws and regulations relating to the protection of the environment. These environmental laws and regulations may impose substantial penalties for noncompliance and substantial liabilities for pollution. Many of these laws and regulations restrict or prohibit the types, quantities and concentration of substances that can be released into the environment and can lead to substantial liabilities for non-compliance or releases. Failure to comply with these laws and regulations may also result in substantial civil and criminal fines and penalties.
 
Comprehensive Environmental Response, Compensation and Liability Act (CERCLA)
 
CERCLA, also known as the “Superfund” law, imposes liability, without regard to fault, on certain classes of persons who are considered to be responsible for the spill or release of a hazardous substance into the environment. Potentially liable persons include the owner or operator of the site where the release occurred and persons who disposed or arranged for the disposal of hazardous substances at the site. Under CERCLA, responsible persons may be subject to joint and several liability. Although CERCLA currently excludes petroleum, natural gas, natural gas liquids and LNG from its definition of “hazardous substances,” this exemption may be limited or modified by the U.S. Congress in the future.
 
Clean Air Act (CAA)
 
The Sabine Pass LNG receiving terminal operations are subject to the federal CAA and comparable state and local laws. We may be required to incur certain capital expenditures over the next several years for air pollution control equipment in connection with maintaining or obtaining permits and approvals addressing other air emission-related issues. We do not believe, however, that operations of the Sabine Pass LNG receiving terminal will be materially adversely affected by any such requirements.
 
The U.S. Supreme Court has ruled that the EPA has authority under existing legislation to regulate carbon dioxide and other heat-trapping gases in mobile source emissions. Mandatory reporting requirements were promulgated by the EPA and finalized on October 30, 2009.  This rule requires mandatory reporting for greenhouse gases from stationary fuel combustion sources.  An additional section would have required reporting for all fugitive emissions throughout the Sabine Pass LNG receiving terminal and

 
3
 

would have impacted our reporting requirements; however, this section was deferred in the final rule. In addition, Congress has considered proposed legislation directed at reducing “greenhouse gas emissions.” It is not possible at this time to predict how future regulations or legislation may address greenhouse gas emissions and impact our business. However, future regulations and laws could result in increased compliance costs or additional operating restrictions and could have a material adverse effect on our business, financial position, results of operations and cash flows.
 
Clean Water Act (CWA)
 
The Sabine Pass LNG receiving terminal operations are also subject to the federal CWA and analogous state and local laws. Pursuant to certain requirements of the CWA, the EPA has adopted regulations concerning discharges of wastewater and storm water runoff. This program requires covered facilities to obtain individual permits, participate in a group permit or seek coverage under an EPA general permit.
 
Resource Conservation and Recovery Act (RCRA)
 
The federal RCRA and comparable state statutes govern the disposal of “hazardous wastes.” In the event any hazardous wastes are generated in connection with the Sabine Pass LNG receiving terminal operations, we are subject to regulatory requirements affecting the handling, transportation, treatment, storage and disposal of such wastes.
 
Endangered Species Act
 
The Sabine Pass LNG receiving terminal operations may also be restricted by requirements under the Endangered Species Act, which seeks to ensure that human activities neither jeopardize endangered or threatened animal, fish and plant species nor destroy or modify their critical habitats.
 
Employees and Labor Relations
 
We have no employees. We rely on our general partner to manage all aspects of the operation and maintenance of the Sabine Pass LNG receiving terminal and the conduct of our business. Because our general partner has no employees, it relies on subsidiaries of Cheniere to provide the personnel necessary to allow it to meet its management obligations to us and to Sabine Pass LNG. As of February 17, 2010, Cheniere had 196 full-time employees. See Note 13—“Related Party Transactions” in our Notes to Consolidated Combined Financial Statements for a discussion of these arrangements.  Cheniere considers its current employee relations to be favorable.
 
Available Information

Our common units have been publicly traded since March 21, 2007, and are traded on the NYSE Amex Equities, formerly the NYSE Alternext US, under the symbol “CQP”. Our principal executive offices are located at 700 Milam Street, Suite 800, Houston, Texas 77002, and our telephone number is (713) 375-5000. Our internet address is http://www.cheniereenergypartners.com. We provide public access to our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to these reports as soon as reasonably practicable after we electronically file those materials with, or furnish those materials to, the Securities and Exchange Commission (“SEC”) under the Exchange Act. These reports may be accessed free of charge through our internet website. We make our website content available for informational purposes only. The website should not be relied upon for investment purposes, nor is it incorporated by reference into this Form 10-K.
 
We will also make available to any stockholder, without charge, copies of our Annual Report on Form 10-K as filed with the SEC. For copies of this, or any other filing, please contact: Cheniere Energy Partners, L.P, Investor Relations Department, 700 Milam Street, Suite 800, Houston, Texas 77002 or call (713) 562-5000. In addition, the public may read and copy any materials we file with the SEC at the SEC’s Public Reference Room at 100 F Street, N.E., Room 1580, Washington, DC 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. The SEC maintains an internet site (www.sec.gov) that contains reports and other information regarding issuers, like us, that file electronically with the SEC.


 
4
 

ITEM 1A.                      RISK FACTORS
 
Limited partner interests are inherently different from the capital stock of a corporation, although many of the business risks to which we are subject are similar to those that would be faced by a corporation engaged in a similar business. The following are some of the important factors that could affect our financial performance or could cause actual results to differ materially from estimates contained in our forward-looking statements. We may encounter risks in addition to those described below. Additional risks and uncertainties not currently known to us, or that we currently deem to be immaterial, may also impair or adversely affect our business, results of operation, financial condition, liquidity and prospects.
 
The risk factors in this report are grouped into the following categories:
 
 
•
Risks Relating to Our Financial Matters;
 
 
•
Risks Relating to Our Business;
 
 
•
Risks Relating to Our Cash Distributions;
 
 
•
Risks Relating to an Investment in Us and Our Common Units; and
 
 
•
Risks Relating to Tax Matters.
 
Risks Relating to Our Financial Matters
 
We have substantial indebtedness, which we will need to refinance in whole or in part at or prior to maturity.
 
As of December 31, 2009, we had $2.2 billion of indebtedness outstanding, consisting primarily of the $550.0 million of 7¼% Senior Secured Notes due 2013 (“2013 Notes”) and $1,633.0 million, net of discount, of 7½% Senior Secured Notes due 2016 (“2016 Notes” and collectively with the 2013 Notes, the “Senior Notes”). We will have to refinance, extend or otherwise satisfy, all or a portion of our indebtedness. We may not be able to refinance, extend or otherwise satisfy our indebtedness as needed, on commercially reasonable terms or at all.
 
Our substantial indebtedness could adversely affect our ability to operate our business and prevent us from satisfying or refinancing our debt obligations.
 
    Our substantial indebtedness could have important adverse consequences, including:
 
 
•
limiting our ability to attract customers;
 
 
•
limiting our ability to compete with other companies that are not as highly leveraged;
 
 
•
limiting our flexibility in and ability to plan for or react to changing market conditions in our industry and to economic downturns, and making us more vulnerable than our less leveraged competitors to an industry or economic downturn;
 
 
•
limiting our ability to use operating cash flow in other areas of our business because we must dedicate a substantial portion of these funds to service debt, including indebtedness that we may incur in the future;
 
 
•
limiting our ability to obtain additional financing to fund our capital expenditures, working capital, acquisitions, debt service requirements or liquidity needs for general business or other purposes; and
 
 
•
resulting in a material adverse effect on our business, results of operations and financial condition if we are unable to service or refinance our indebtedness or obtain additional financing, as needed.
 
Our substantial indebtedness and the restrictive covenants contained in our debt agreements may not allow us the flexibility that we need to operate our business in an effective and efficient manner and may prevent us from taking advantage of strategic and financial opportunities that would benefit our business.

If we are unsuccessful in operating our business due to our substantial indebtedness or other factors, we may be unable to repay, refinance, or extend our indebtedness on commercially reasonable terms or at all.
 
To service our indebtedness, we will require significant amounts of cash.
 
We will require significant cash flow from operations in order to make annual interest payments of approximately $164.8 million on the Senior Notes. Our ability to make payments on and to refinance our indebtedness, including the Senior Notes, and to fund capital expenditures, will depend on our ability to generate cash in the future. Our business may not generate sufficient cash flow from operations, currently anticipated costs may increase or future borrowings may not be available to us, which could cause us to be unable to pay or refinance our indebtedness, including the Senior Notes, or to fund our other liquidity needs.

 
5
 
 
Our ability to generate needed amounts of cash is substantially dependent upon Sabine Pass LNG’s TUAs with three customers, and we will be materially and adversely affected if any customer fails to perform its TUA obligations for any reason.
 
We are dependent, for substantially all of our operating revenues and cash flows, on TUAs with Chevron and Total, each of which has agreed to pay us approximately $125 million annually, and with Cheniere Marketing, which is required to pay us approximately $250 million annually. We are dependent on each customer’s continued willingness and ability to perform its obligations under its TUA. We are also exposed to the credit risk of the guarantors of these customers’ obligations under their respective TUAs in the event that we must seek recourse under a guaranty. If any customer fails to perform its obligations under its TUA, our business, results of operations, financial condition and prospects could be materially and adversely affected, even if we were ultimately successful in seeking damages from that customer or its guarantor for a breach of the TUA.
 
Cheniere Marketing continues to develop its business, has limited capital and lacks a credit rating. In addition, Cheniere, which has guaranteed Cheniere Marketing’s TUA obligations, has a non-investment grade corporate rating of CCC+ from Standard and Poor’s. Accordingly, we believe that Cheniere Marketing and Cheniere have a higher risk of being financially unable to perform their obligations under the Cheniere Marketing TUA than either Chevron or Total have with respect to their TUAs. Although each of the TUA counterparties faces a risk that it will not be able to enter into commercial arrangements for the use of its capacity at the Sabine Pass LNG receiving terminal to support the payment of its obligations under its TUA, due to negative developments in the LNG industry or for other reasons, that risk and the potential for that risk to adversely affect us are greater for Cheniere Marketing than for Total and Chevron. The principal risks attendant to Cheniere Marketing’s future ability to generate operating cash flow to support its TUA obligations include the following:
 
 
•
Cheniere Marketing does not have unconditional agreements or arrangements for any supplies of LNG, or for the utilization of capacity that it has contracted for under its TUA with us and may not be able to obtain such agreements or arrangements on economical terms, or at all;
 
 
•
Cheniere Marketing does not have unconditional commitments from customers for the purchase of the natural gas it proposes to sell from the Sabine Pass LNG receiving terminal, and it may not be able to obtain commitments or other arrangements on economical terms, or at all; and
 
 
•
even if Cheniere Marketing is able to arrange for supplies and transportation of LNG to the Sabine Pass LNG receiving terminal, and for transportation and sales of natural gas to customers, it may experience negative cash flows and adverse liquidity effects due to fluctuations in supply, demand and price for LNG, for transportation of LNG, for natural gas and for storage and transportation of natural gas.
 
In pursuing each aspect of its planned business, Cheniere Marketing will encounter intense competition, including competition from major energy companies and other competitors with significantly greater resources. Cheniere Marketing will also compete with Sabine Pass LNG’s other customers and may compete with Cheniere and its other subsidiaries that are developing or operating other LNG receiving terminals and related infrastructure, which may include vessels, pipelines and LNG storage. Cheniere Marketing’s regasification capacity at the Sabine Pass LNG receiving terminal, in particular, will be marketed in competition with existing capacity and additional future capacity offered by other LNG receiving terminals that currently exist or that may be completed or expanded in the future by Cheniere affiliates or others.
 
Any or all of these factors, as well as other risk factors that we or Cheniere Marketing may not be able to anticipate, control or mitigate, could materially and adversely affect the business, results of operations, financial condition, prospects and liquidity of Cheniere Marketing, which in turn could have a material adverse effect upon us.

The indenture governing the Senior Notes contains restrictions that limit our flexibility in operating our business.
 
The indenture, dated as of November 9, 2006, governing the Senior Notes (the “Sabine Pass Indenture”) contains several significant covenants that, among other things, restrict our ability to:
 
 
•
incur additional indebtedness;
 
 
•
create liens on our assets; and
 
 
•
engage in sale and leaseback transactions and mergers or acquisitions and to make equity investments.
 
    Under some circumstances, these restrictive covenants may not allow us the flexibility that we need to operate our business in an effective and efficient manner and may prevent us from taking advantage of strategic and financial opportunities that would benefit our business. See also “—Risks Relating to Our Cash Distributions—Sabine Pass LNG may be restricted under the terms of the    

 
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Sabine Pass Indenture from making distributions to us and from incurring additional indebtedness under certain circumstances, which may limit our ability to pay or increase distributions to our unitholders.”
 
If we fail to comply with the restrictions in the Sabine Pass Indenture or any other subsequent financing agreements, a default may allow the creditors, if the agreements so provide, to accelerate the related indebtedness as well as any other indebtedness to which a cross-acceleration or cross-default provision applies.
 
We could incur more indebtedness in the future, which could exacerbate the risks associated with our substantial leverage.
 
The Sabine Pass Indenture does not prohibit us from incurring additional indebtedness, including additional senior or secured indebtedness, and other liabilities, or from pledging assets to secure such indebtedness and liabilities. The incurrence of additional indebtedness and, in particular, the granting of a security interest to secure additional indebtedness, could adversely affect our business, results of operations and financial condition if we are unable to service our indebtedness.
  
Each customer’s TUA for capacity at the Sabine Pass LNG receiving terminal is subject to termination under certain circumstances.
 
Each of the long-term TUAs with Total, Chevron and Cheniere Marketing contains various termination rights. For example, each customer may terminate its TUA if the Sabine Pass LNG receiving terminal experiences a force majeure delay for longer than 18 months, fails to redeliver a specified amount of natural gas in accordance with the customer’s redelivery nominations or fails to accept and unload a specified number of the customer’s proposed LNG cargoes. We may not be able to replace these TUAs on desirable terms, or at all, if they are terminated.
 
Risks Relating to Our Business
 
Operation of our LNG receiving terminal involves significant risks.
 
Our LNG receiving terminal faces operational risks, including the following:
 
 
•
performing below expected levels of efficiency;
 
 
•
breakdown or failures of equipment or systems;
 
 
•
operational errors by vessel or tug operators or others;
 
 
•
operational errors by us or any contracted facility operator or others;
 
 
•
labor disputes; and
 
 
•
weather-related interruptions of operations.

To maintain the cryogenic readiness of the Sabine Pass LNG receiving terminal, Sabine Pass LNG may need to purchase and process LNG. The cost of such LNG may exceed our estimates, and we may not be able to acquire it at an affordable price, or at all. Furthermore, even if Sabine Pass LNG is able to acquire LNG, it may not be able to resell the regasified LNG for a profit or at all.
 
LNG storage tanks and other equipment at the Sabine Pass LNG receiving terminal must be maintained in a state of cryogenic readiness for conducting operations and to provide services under Sabine Pass LNG’s TUAs.  Sabine Pass LNG may need to acquire LNG to maintain the cryogenic readiness of its LNG receiving terminal to provide services to TUA customers. The actual cost to obtain such LNG could exceed our estimates, and the cost overrun could be significant.
 
Risks associated with acquiring LNG include the following:
 
 
•
Sabine Pass LNG may be unable to enter into contracts for the purchase of the LNG and may be unable to obtain vessels to deliver such LNG, on terms reasonably acceptable to it or at all;
 
 
•
Sabine Pass LNG may bear the commodity price risk associated with purchasing the LNG, holding it in inventory for a period of time and selling the regasified LNG; and
 
 
•
Sabine Pass LNG may be unable to obtain financing for the purchase and shipment of the LNG on terms that are reasonably acceptable to it or at all.
 
 

 
7
 
 
The failure of Sabine Pass LNG to obtain LNG, LNG vessels or both, on economical terms, or the inability to finance the purchase of LNG for maintenance of cryogenic readiness to provide services under the TUAs, could provide our TUA customers with the opportunity to interrupt or terminate their payment under their respective TUAs. Any of these occurrences could have a material adverse effect on our business, results of operations, financial condition and prospects.
 
Sabine Pass LNG may be required to purchase natural gas to provide fuel at the Sabine Pass LNG receiving terminal, which would increase operating costs and could have a material adverse effect on our results of operations.
 
Sabine Pass LNG’s three TUAs provide for an in-kind deduction of 2% of the LNG delivered to the Sabine Pass LNG receiving terminal, which it uses primarily as fuel for revaporization and self-generated power and to cover natural gas unavoidably lost at the facility. There is a risk that this 2% in-kind deduction will be insufficient for these needs and that Sabine Pass LNG will have to purchase additional natural gas from third parties. Sabine Pass LNG will bear the cost and risk of changing prices for any such fuel.
 
Hurricanes or other disasters could adversely affect us.
 
In August and September of 2005, Hurricanes Katrina and Rita damaged coastal and inland areas located in Texas, Louisiana, Mississippi and Alabama. Construction at the Sabine Pass LNG receiving terminal site was temporarily suspended in connection with Hurricane Katrina, as a precautionary measure. Approximately three weeks after the occurrence of Hurricane Katrina, the terminal site was again secured and evacuated in anticipation of Hurricane Rita, the eye of which made landfall to the east of the site. As a result of these 2005 storms and related matters, the Sabine Pass LNG receiving terminal experienced construction delays and increased costs. In September 2008, Hurricane Ike struck the Texas and Louisiana coast, and we experienced damage at the Sabine Pass LNG receiving terminal.
 
Future storms and related storm activity and collateral effects, or other disasters such as explosions, fires, floods or accidents, could result in damage to, or interruption of operations at, the Sabine Pass LNG receiving terminal or related infrastructure.  If there are changes in the global climate, storm frequency and intensity may increase; should it result in rising seas, our coastal operations would be impacted.
 
Failure to obtain and maintain approvals and permits from governmental and regulatory agencies with respect to the operation of the Sabine Pass LNG receiving terminal could impede operations and could have a material adverse effect on us.
 
The operation of the Sabine Pass LNG receiving terminal is a highly regulated activity. The FERC’s approval under Section 3 of the NGA, as well as several other material governmental and regulatory approvals and permits, are required in order to operate the Sabine Pass LNG receiving terminal. Although we have obtained all of the necessary authorizations to operate the Sabine Pass LNG receiving terminal, such authorizations are subject to ongoing conditions imposed by regulatory agencies, and additional approval and permit requirements may be imposed. Failure to obtain and maintain any of these approvals and permits could have a material adverse effect on our business, results of operations, financial condition and prospects.
 
We are entirely dependent on Cheniere, including employees of Cheniere and its subsidiaries, for key personnel, and a loss of key personnel could have a material adverse effect on our business.
 
As of February 15, 2010, Cheniere and its subsidiaries had 196 full-time employees. We have contracted with subsidiaries of Cheniere to provide the personnel necessary for the operation, maintenance and management of the Sabine Pass LNG receiving terminal. We face competition for these highly skilled employees in the immediate vicinity of the Sabine Pass LNG receiving terminal and more generally from the Gulf Coast hydrocarbon processing and construction industries.
 
Our general partner’s executive officers are officers and employees of Cheniere and its affiliates. We do not maintain key person life insurance policies on any personnel, and our general partner does not have any employment contracts or other agreements with key personnel binding them to provide services for any particular term. The loss of the services of any of these individuals could have a material adverse effect on our business. In addition, our future success will depend in part on our general partner’s ability to engage, and Cheniere’s ability to attract and retain, additional qualified personnel.
 
We have numerous contractual and commercial relationships, and conflicts of interest, with Cheniere and its affiliates, including Cheniere Marketing.
 
We have agreements to compensate and to reimburse expenses of affiliates of Cheniere. In addition, Sabine Pass LNG has entered into a TUA with Cheniere Marketing, under which Cheniere Marketing will be able to derive substantial economic benefits. All of these agreements involve conflicts of interest between us, on the one hand, and Cheniere and its other affiliates, on the other hand.
 
 
8
 
 
We are dependent on Cheniere and its affiliates to provide services to us.  If Cheniere or its affiliates are unable or unwilling to perform according to the negotiated terms and timetable of their respective agreement for any reason or terminates their agreement, we would be required to engage a substitute service provider.  This would likely result in a significant interference with operations and increased costs.
 
Sabine Pass LNG is subject to significant operating hazards and uninsured risks, one or more of which may create significant liabilities and losses that could have a material and adverse effect on us.
 
The operation of the Sabine Pass LNG receiving terminal is subject to the inherent risks associated with this type of operation, including explosions, pollution, release of toxic substances, fires, hurricanes and adverse weather conditions, and other hazards, each of which could result in significant delays in commencement or interruptions of operations and/or in damage to or destruction of the Sabine Pass LNG receiving terminal or damage to persons and property. In addition, operations at the Sabine Pass LNG receiving terminal and the facilities and vessels of third parties on which our operations are dependent face possible risks associated with acts of aggression or terrorism.
 
We do not, nor do we intend to, maintain insurance against all of these risks and losses. We may not be able to maintain desired or required insurance in the future at rates that we consider reasonable. The occurrence of a significant event not fully insured or indemnified against could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
Existing and future environmental and similar laws and regulations could result in increased compliance costs or additional operating costs and restrictions.
 
Our business is and will be subject to extensive federal, state and local laws and regulations that control, among other things, discharges to air and water; the handling, storage and disposal of hazardous chemicals, hazardous waste, and petroleum products; and remediation associated with the release of hazardous substances. Many of these laws and regulations, such as the CAA, the Oil Pollution Act, the CWA, and the RCRA, and analogous state laws and regulations, restrict or prohibit the types, quantities and concentration of substances that can be released into the environment in connection with the operation of the Sabine Pass LNG receiving terminal and require us to maintain permits and provide governmental authorities with access to the facility for inspection and reports related to our compliance. Violation of these laws and regulations could lead to substantial fines and penalties or to capital expenditures related to pollution control equipment that could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects. CERCLA and similar state laws impose liability, without regard to fault or the lawfulness of the original conduct, for the release of certain types or quantities of hazardous substances into the environment. As the owner and operator of the Sabine Pass LNG receiving terminal, we could be liable for the costs of cleaning up hazardous substances released into the environment and for damage to natural resources.
 
There are numerous regulatory approaches currently in effect or being considered to address greenhouse gases, including possible future U.S. treaty commitments, new federal or state legislation that may impose a carbon emissions tax or establish a cap-and-trade program, and regulation by the EPA. For example, the adoption of frequently proposed legislation implementing a carbon tax on energy sources that emit carbon dioxide into the atmosphere may have a material adverse effect on the ability of Sabine Pass LNG’s customers, particularly Cheniere Marketing, (i) to import LNG, if imposed on them as importers of potential emission sources, or (ii) to sell regasified LNG, if imposed on them or their customers as natural gas suppliers or consumers. In addition, as Sabine Pass LNG consumes retainage gas at the Sabine Pass LNG receiving terminal, this carbon tax may also be imposed on Sabine Pass LNG directly.
 
There have also been proposals for a mandatory cap and trade program to reduce greenhouse gas emissions. In June 2009, the U.S. House of Representatives passed a comprehensive climate change and energy bill, the American Clean Energy and Security Act, and the U.S. Senate is considering similar legislation that would, among other things, impose a nationwide cap on greenhouse gas emissions and require major sources to obtain “allowances” to meet that cap. In September 2009, the EPA promulgated a rule requiring certain emitters of greenhouse gases to monitor and report their greenhouse gas emissions to the EPA. In addition, in response to the 2007 U.S. Supreme Court ruling in Massachusetts v. EPA that the EPA has authority to regulate carbon dioxide emissions under the Clean Air Act, the EPA has issued and is considering several additional proposals, including one that would require best available control technology for greenhouse gas emissions whenever certain stationary sources are built or significantly modified. In addition, two U.S. federal appeals courts have reinstated lawsuits permitting individuals, state attorneys general and others to pursue claims against major utility, coal, oil and chemical companies on the basis that those companies have created a public nuisance due to their emissions of carbon dioxide. Climate change initiatives and other efforts to reduce greenhouse gas emissions like those described above or otherwise may require additional controls on the operation of the Sabine Pass LNG receiving terminal and increased costs to implement and maintain such controls.
 
 
9
 

Other future legislation and regulations, such as those relating to the transportation and security of LNG imported to the Sabine Pass LNG receiving terminal through the Sabine Pass Channel, could cause additional expenditures, restrictions and delays in our business, the extent of which cannot be predicted and which may require us to limit substantially, delay or cease operations in some circumstances. Revised, reinterpreted or additional laws and regulations that result in increased compliance costs or additional operating costs and restrictions could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
Failure of imported LNG to be a competitive source of energy for North American markets could adversely affect TUA customers, particularly Cheniere Marketing, and could materially and adversely affect our business, results of operations, financial condition and prospects.
 
Operations at the Sabine Pass LNG receiving terminal will be dependent upon the ability of terminal customers to import LNG supplies into the U.S., which is primarily dependent upon LNG being a competitive source of energy in North America. In North America, due mainly to a historically abundant supply of natural gas, imported LNG has not historically been a major energy source. Our business plan is based, in part, on the belief that LNG can be produced internationally and delivered to North America at a lower cost than the cost to produce some domestic supplies of natural gas, or other alternative energy sources. Through the use of improved exploration technologies, additional sources of natural gas may be discovered in North America, which could further increase the available supply of natural gas and could result in natural gas being available at a lower cost than imported LNG. In addition to natural gas, LNG also competes in North America with other sources of energy, including coal, oil, nuclear, hydroelectric, wind and solar energy.
 
Other continents have a longer history of importing LNG and, due to their geographic proximity to LNG producers and limited pipeline access to natural gas supplies, may be willing and able to pay more for LNG, thereby reducing or eliminating the supply of LNG available in North American markets. Current and futures prices for natural gas in markets that compete with North America have been higher than prices for natural gas in North America, which has adversely affected the volume of LNG imports into North America. If LNG deliveries to North America continue to be constrained due to stronger demand from these competing markets, the ability of Sabine Pass LNG’s TUA customers to import LNG into North America on a profitable basis may be adversely affected.
 
Political instability in foreign countries that have supplies of natural gas, or strained relations between such countries and the U.S., may also impede the willingness or ability of LNG suppliers and merchants in such countries to export LNG to the U.S. Furthermore, some foreign suppliers of LNG may have economic or other reasons to direct their LNG to non-U.S. markets or to competitors’ LNG receiving terminals in the U.S.
 
As a result of these and other factors, LNG may not be a competitive source of energy in North America. The failure of LNG to be a competitive supply alternative to domestic natural gas, oil and other alternative energy sources could impede TUA customers’ ability to import LNG into North America on a commercial basis. Any significant impediment to the ability to import LNG into the United States generally or to the Sabine Pass LNG receiving terminal specifically could have a material adverse effect on TUA customers, particularly Cheniere Marketing, and on our business, results of operations, financial condition and prospects.

The inability to import LNG into the U.S. may also limit the LNG assets being constructed and, therefore, our potential acquisition opportunities, which may limit our ability to increase distributions to our unitholders.
 
Cyclical or other changes in the demand for LNG regasification capacity may adversely affect the performance of TUA customers, particularly Cheniere Marketing, and could reduce our operating revenues and may cause us operating losses.
 
The utilization of the Sabine Pass LNG receiving terminal could be subject to cyclical swings, reflecting alternating periods of under-supply and over-supply of LNG importation capacity and available natural gas, principally due to the combined impact of several factors, including:
 
 
•
additions to competitive regasification capacity in North America, Europe, Asia and other markets, which could divert LNG from the Sabine Pass LNG receiving terminal;
 
 
•
insufficient LNG liquefaction capacity worldwide;
 
 
•
insufficient LNG tanker capacity;
 
 
•
reduced demand and lower prices for natural gas;
 
 
•
increased natural gas production deliverable by pipelines, which could suppress demand for LNG;
 
 
•
cost improvements that allow competitors to offer LNG regasification services at reduced prices;
 
10
 
 
•
changes in supplies of, and prices for, alternative energy sources such as coal, oil, nuclear, hydroelectric, wind and solar energy, which may reduce the demand for natural gas;
 
 
•
changes in regulatory, tax or other governmental policies regarding imported LNG, natural gas or alternative energy sources, which may reduce the demand for imported LNG and/or natural gas;
 
 
•
adverse relative demand for LNG in North America compared to other markets, which may decrease LNG imports into North America; and
 
 
•
cyclical trends in general business and economic conditions that cause changes in the demand for natural gas.
 
These factors could materially and adversely affect the ability of TUA customers, including Cheniere Marketing, to procure supplies of LNG to be imported into North America and to procure customers for regasified LNG at economical prices, or at all. In addition, these factors may result in fewer LNG assets being constructed or available for acquisition by us at any given time and, therefore, limit our ability to increase distributions to unitholders.
 
We face competition from competitors with far greater resources.
 
Many competing companies have secured access to, or are pursuing development or acquisition of, LNG import infrastructure to serve the U.S. natural gas market. Some industry analysts have predicted substantial excess LNG receiving capacity in North America for at least several years based on terminals currently in operation or under construction. Our competitors in the U.S. include major energy corporations (e.g., BG Group plc, BP plc, Chevron Corporation, ConocoPhillips and Dow Chemical). In addition, other competitors have developed or reopened additional LNG receiving terminals in Europe, Asia and other markets, which also compete with the Sabine Pass LNG receiving terminal. Almost all of these competitors have longer operating histories, more development experience, greater name recognition, larger staffs and substantially greater financial, technical and marketing resources and access to LNG supply than we and our affiliates do. The superior resources that these competitors have available for deployment could allow them to compete successfully against us, which could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
Insufficient development of additional LNG liquefaction capacity worldwide could adversely affect the performance of TUA customers, particularly Cheniere Marketing, and could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
Commercial development of an LNG liquefaction facility takes a number of years and requires substantial capital investment. Many factors could negatively affect continued development of LNG liquefaction facilities, including:
 
 
•
increased construction costs;
 
 
•
economic downturns, increases in interest rates or other events that may affect the availability of sufficient financing for LNG projects on commercially reasonable terms;
 
 
•
decreases in the price of LNG and natural gas, which might decrease the expected returns relating to investments in LNG projects;
 
 
•
the inability of project owners or operators to obtain governmental approvals to construct or operate LNG facilities;
 
 
•
political unrest in exporting countries or local community resistance in such countries to the siting of LNG facilities due to safety, environmental or security concerns; and
 
 
•
any significant explosion, spill or similar incident involving an LNG liquefaction facility or LNG carrier.
 
There may be shortages of LNG vessels worldwide, which could adversely affect the performance of TUA customers, particularly Cheniere Marketing, and could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
The construction and delivery of LNG vessels require significant capital and long construction lead times, and the availability of the vessels could be delayed to the detriment of the TUA customers because of:
 
 
•
an inadequate number of shipyards constructing LNG vessels and a backlog of orders at these shipyards;
 
 
•
political or economic disturbances in the countries where the vessels are being constructed;
 
 
•
changes in governmental regulations or maritime self-regulatory organizations;
 
 
•
work stoppages or other labor disturbances at the shipyards;
 
 
11
 
 
 
•
bankruptcy or other financial crisis of shipbuilders;
 
 
•
quality or engineering problems;
 
 
•
weather interference or a catastrophic event, such as a major earthquake, tsunami or fire; and
 
 
•
shortages of or delays in the receipt of necessary construction materials.
 
Decreases in the demand for and price of natural gas could lead to reduced development of LNG projects worldwide, which could adversely affect the performance of TUA customers, particularly Cheniere Marketing, and could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
The development of domestic LNG receiving terminals and LNG projects generally is based on assumptions about the future price of natural gas and the availability of imported LNG. Natural gas prices have been, and are likely to continue to be, volatile and subject to wide fluctuations in response to one or more of the following factors:
 
 
•
relatively minor changes in the supply of, and demand for, natural gas in relevant markets;
 
 
•
political conditions in international natural gas producing regions;
 
 
•
the extent of domestic production and importation of natural gas in relevant markets;
 
 
•
the level of demand for LNG and natural gas in relevant markets, including the effects of economic downturns or upturns;
 
 
•
weather conditions;
 
 
•
the competitive position of natural gas as a source of energy compared with other energy sources; and
 
 
•
the effect of government regulation on the production, transportation and sale of natural gas.
 
Adverse trends or developments affecting any of these factors could result in decreases in the price of natural gas, leading to reduced development of LNG projects worldwide. Such reductions could adversely affect the performance of TUA customers, particularly Cheniere Marketing, and could have a material adverse effect on our business, results of operations, financial condition, liquidity and prospects.
 
We may experience increased labor costs, and the unavailability of skilled workers or our failure to attract and retain key personnel could adversely affect us.
 
We are dependent upon the available labor pool of skilled employees. We compete with other energy companies and other employers to attract and retain qualified personnel with the technical skills and experience required to operate the Sabine Pass LNG receiving terminal and to provide TUA customers with the highest quality service. Our affiliates who hire personnel on our behalf are also subject to the Fair Labor Standards Act, which governs such matters as minimum wage, overtime and other working conditions. A shortage in the labor pool of skilled workers or other general inflationary pressures or changes in applicable laws and regulations could make it more difficult for us to attract and retain personnel and could require an increase in the wage and benefits packages that we offer, thereby increasing our operating costs. For example, in the aftermaths of Hurricanes Katrina and Rita, Bechtel and certain subcontractors temporarily experienced a shortage of available skilled labor necessary to meet the requirements of the construction plan. As a result, we agreed to change orders with Bechtel concerning additional activities and expenditures to mitigate the hurricanes’ effects on the construction of the Sabine Pass LNG receiving terminal. Any increase in our operating costs could materially and adversely affect our business, results of operations, financial condition and prospects.
 
Our lack of diversification could have an adverse effect on our financial condition and results of operations.
 
Substantially all of our anticipated revenue in 2010 will be dependent upon one asset, the Sabine Pass LNG receiving terminal located in southern Louisiana. Due to our lack of asset and geographic diversification, an adverse development at the Sabine Pass LNG receiving terminal or in the LNG industry would have a significantly greater impact on our financial condition and results of operations than if we maintained more diverse assets and operating areas.
 
Terrorist attacks or military campaigns may adversely impact our business.
 
A terrorist incident may result in temporary or permanent closure of existing LNG facilities, including the Sabine Pass LNG receiving terminal, which could increase our costs and decrease our cash flows, depending on the duration of the closure. Operations at the Sabine Pass LNG receiving terminal could also become subject to increased governmental scrutiny that may result in additional security measures at a significant incremental cost to us. In addition, the threat of terrorism and the impact of military campaigns may

 
12
 

lead to continued volatility in prices for natural gas that could adversely affect TUA customers, particularly Cheniere Marketing, including their ability to satisfy their obligations to us under their TUAs.
 
If we do not make acquisitions on economically acceptable terms, our future growth and our ability to increase distributions to our unitholders will be limited.
 
Our ability to grow depends on our ability to make accretive acquisitions. We may be unable to make accretive acquisitions for any of the following reasons:
 
 
•
we are unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts with them;
 
 
•
we are unable to obtain necessary governmental approvals;
 
 
•
we are unable to obtain financing for the acquisitions on economically acceptable terms, or at all;
 
 
•
we are unable to secure adequate customer commitments to use the acquired facilities; or
 
 
•
we are outbid by competitors.
 
If we are unable to make accretive acquisitions, then our future growth and ability to increase distributions to our unitholders will be limited.
 
We intend to pursue acquisitions of additional LNG receiving terminals, natural gas pipelines and related assets in the future, either directly from Cheniere or from third parties. However, Cheniere is not obligated to offer us any of these assets. If Cheniere does offer us the opportunity to purchase assets, we may not be able to successfully negotiate a purchase and sale agreement and related agreements, we may not be able to obtain any required financing for such purchase and we may not be able to obtain any required governmental and third-party consents. The decision whether or not to accept such offer, and to negotiate the terms of such offer, will be made by the conflicts committee of our general partner, which may decline the opportunity to accept such offer for a variety of reasons, including a determination that the acquisition of the assets at the proposed purchase price would not result in an increase, or a sufficient increase, in our adjusted operating surplus per unit within an appropriate timeframe.
 
If we make acquisitions, they could adversely affect our business and ability to make distributions to our unitholders.
 
If we make any acquisitions, they will involve potential risks, including:
 
 
•
an inability to integrate successfully the businesses that we acquire with our existing business;
 
 
•
a decrease in our liquidity by using a significant portion of our available cash or borrowing capacity to finance the acquisition;
 
 
•
the assumption of unknown liabilities;
 
 
•
limitations on rights to indemnity from the seller;
 
 
•
mistaken assumptions about the cash generated, or to be generated, by the business acquired or the overall costs of equity or debt;
 
 
•
the diversion of management’s and employees’ attention from other business concerns; and
 
 
•
unforeseen difficulties encountered in operating new business segments or in new geographic areas.
 
If we consummate any future acquisitions, our capitalization and results of operations may change significantly, and our unitholders will not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in determining the application of our future funds and other resources. In addition, if we issue additional units in connection with future growth, our existing unitholders’ interest in us will be diluted, and distributions to our unitholders may be reduced.
 
Risks Relating to Our Cash Distributions
 
Sabine Pass LNG may be restricted under the terms of the Sabine Pass Indenture from making distributions to us and from incurring additional indebtedness under certain circumstances, which may limit our ability to pay or increase distributions to our unitholders.

 
13
 

The Sabine Pass Indenture restricts payments that Sabine Pass LNG can make to us in certain events and limits the indebtedness that Sabine Pass LNG can incur. Sabine Pass LNG is permitted to pay distributions to us only after the following payments have been made:
 
 
•
an operating account has been funded with amounts sufficient to cover the succeeding 45 days of operating and maintenance expenses, maintenance capital expenditures and obligations, if any, under an assumption agreement and a state tax sharing agreement;
 
 
•
one-sixth of the amount of interest due on the Senior Notes on the next interest payment date (plus any shortfall from any such month subsequent to the preceding interest payment date) has been transferred to a debt payment account;
 
 
•
outstanding principal on the Senior Notes then due and payable has been paid;
 
 
•
taxes payable by Sabine Pass LNG or the guarantors of the Senior Notes and permitted payments in respect of taxes have been paid; and
 
 
•
the debt service reserve account has been replenished with the amount (or acceptable letters of credit or acceptable guarantees in respect of such amount) required to make the next interest payment on the Senior Notes, which amount was approximately $82.4 million as of December 31, 2009.
 
In addition, Sabine Pass LNG will only be able to make distributions to us in the event that it could, among other things, incur at least $1.00 of additional indebtedness under the fixed charge coverage ratio test of 2:1 at the time of payment and after giving pro forma effect to the distribution.
 
Sabine Pass LNG is also prohibited under the Sabine Pass Indenture from paying distributions to us or incurring additional indebtedness upon the occurrence of any of the following events, among others:
 
 
•
a default for 30 days in the payment of interest on, or additional interest, if any, with respect to, the Senior Notes;
 
 
•
a failure to pay any principal of, or premium, if any, on the Senior Notes;
 
 
•
a failure by Sabine Pass LNG to comply with various covenants in the Sabine Pass Indenture;
 
 
•
a failure to observe any other agreement in the Sabine Pass Indenture beyond any specified cure periods;
 
 
•
a default under any mortgage, indenture or instrument governing any indebtedness for borrowed money by Sabine Pass LNG in excess of $25.0 million if such default results from a failure to pay principal or interest on, or results in the acceleration of, such indebtedness;
 
 
•
a final money judgment or decree (not covered by insurance) in excess of $25.0 million is not discharged or stayed within 60 days following entry;
 
 
•
a failure of any material representation or warranty in the security documents entered into in connection with the indenture to be correct;
 
 
•
the Sabine Pass LNG receiving terminal project is abandoned; or
 
 
•
certain events of bankruptcy or insolvency.
 
Sabine Pass LNG’s inability to pay distributions to us or to incur additional indebtedness as a result of the foregoing restrictions in the Sabine Pass Indenture may inhibit our ability to pay or increase distributions to our unitholders.
 
The fixed charge coverage ratio test contained in the Sabine Pass Indenture could prevent Sabine Pass LNG from making cash distributions to us. As a result, we may be prevented from making distributions to our unitholders, which could materially and adversely affect the market price of our common units.
 
Sabine Pass LNG is not permitted to make cash distributions to us if its consolidated cash flow is not at least twice its fixed charges, calculated as required in the indenture. In order to satisfy this fixed charge coverage ratio test, we estimate that Sabine Pass LNG’s consolidated cash flow, as defined in the Sabine Pass Indenture, must be greater than approximately $375 million.
 
Cheniere Marketing continues to develop its business, has limited capital and lacks a credit rating. It may never develop its business, assets or revenues sufficiently to pay its fees under its TUA. Cheniere has guaranteed 100% of the obligations of Cheniere Marketing under its TUA. Cheniere has a non-investment grade corporate rating of CCC+ from Standard & Poor’s. If Cheniere does not receive sufficient future cash flows from businesses that Cheniere is developing, Cheniere may be unable to perform its guarantee of the Cheniere Marketing TUA.
 
 
14
 
 
In addition, even if Sabine Pass LNG receives the contracted payments under the Cheniere Marketing TUA, the fixed charge coverage test will not be satisfied if those payments do not constitute revenues under U.S. generally accepted accounting principles, or GAAP, as then in effect and as provided in the Sabine Pass Indenture. Because the Cheniere Marketing TUA is an agreement between related parties, payments under the Cheniere Marketing TUA may not constitute revenues under GAAP as currently in effect if Cheniere Marketing is determined to lack economic substance apart from Sabine Pass LNG. We believe Cheniere Marketing could be determined to lack economic substance apart from Sabine Pass LNG if, for example, Cheniere Marketing has no substantive business and is not pursuing, and has no prospect of developing, any substantive business apart from its TUA with Sabine Pass LNG.
 
If we do not receive distributions from Sabine Pass LNG, we may not be able to continue to make distributions to our unitholders, which could have a material and adverse effect on the perceived value of our partnership and the market price of our common units.
 
The Sabine Pass Indenture may prevent Sabine Pass LNG from engaging in certain beneficial transactions.
 
In addition to restrictions on the ability of Sabine Pass LNG to make distributions or incur additional indebtedness, the Sabine Pass Indenture also contains various other covenants that may prevent it from engaging in beneficial transactions, including limitations on the ability of Sabine Pass LNG or certain of its subsidiaries to:
 
 
•
make certain investments;
 
 
•
purchase, redeem or retire equity interests;
 
 
•
issue preferred stock;
 
 
•
sell or transfer assets;
 
 
•
incur liens;
 
 
•
enter into transactions with affiliates;
 
 
•
consolidate, merge, sell or lease all or substantially all of its assets; and
 
 
•
enter into sale and leaseback transactions.
 
Management fees and cost reimbursements due to our general partner and its affiliates will reduce cash available to pay distributions to our unitholders.
 
We will pay significant management fees to our general partner and its affiliates and reimburse them for expenses incurred on our behalf, which will reduce our cash available for distribution to our unitholders. These fees and expenses are payable as follows:
 
 
•
under a services agreement, we pay an affiliate of Cheniere an administrative fee of $10.0 million per year (as adjusted for inflation) for general and administrative services for our benefit. This fee does not include reimbursements by us of direct expenses that the affiliate incurs on our behalf, such as salaries of operational personnel performing services on-site at the Sabine Pass LNG receiving terminal and the cost of their employee benefits, including 401(k) plan, pension and health insurance benefits;
 
 
•
under an operation and maintenance agreement with an affiliate of Cheniere, Sabine Pass LNG pays a fixed monthly fee of $130,000 (indexed for inflation) and reimburses our general partner for its operating expenses, which consist primarily of labor expenses. Cheniere’s affiliate, under certain circumstances, will be entitled to a bonus equal to 50% of the salary component of labor costs;  
 
 
•
under a management services agreement with an affiliate of Cheniere, Sabine Pass LNG pays a fixed monthly fee of $520,000 (indexed for inflation); and
 
 
•
we estimate that our partnership will incur costs of approximately $2.5 million per year, adjusted for inflation at 2½% per year, for tax compliance and publicly traded partnership tax reporting, accounting, SEC reporting and other costs of operating as a publicly traded partnership..
 
Our general partner and its affiliates will also be entitled to reimbursement for all other direct expenses that they incur on our behalf. The payment of fees to our general partner and its affiliates and the reimbursement of expenses could adversely affect our ability to pay cash distributions to our unitholders.
 
 
15
 
 
The amount of cash that we have available for distributions to our unitholders will depend primarily on our cash flow and not solely on profitability.
 
The amount of cash that we will have available for distributions will depend primarily on our cash flow, including cash reserves and working capital or other borrowings, and not solely on profitability, which will be affected by non-cash items. As a result, we may make cash distributions during periods when we record losses, and we may not make cash distributions during periods when we record net income.
 
We may not be able to increase the distributions on our common units unless we are able to make accretive acquisitions, which would require us to obtain one or more sources of funding.
 
We may not be able to increase distributions on our common units by generating additional cash flows from the Sabine Pass LNG receiving terminal because the entire capacity of the Sabine Pass LNG receiving terminal has already been reserved under fixed fee TUAs with three customers. As a result, we may need to make accretive acquisitions of additional cash-generating assets and operations in order to increase the quarterly distributions on our common units.
 
To fund acquisitions, we will need to pursue a variety of sources of funding, including debt and/or equity financings. Our ability to obtain these or other types of financing will depend, in part, on factors beyond our control, such as the status of various debt and equity markets at the time financing is sought and such markets’ view of our industry and prospects at such time. In particular, the currently tight lending conditions in the U.S. credit markets may make it more time consuming and expensive for us to obtain financing, if we can obtain such financing at all. Accordingly, we may not be able to obtain financing for acquisitions on terms that are acceptable to us, if at all.
 
Risks Relating to an Investment in Us and Our Common Units
 
Our general partner and its affiliates have conflicts of interest and limited fiduciary duties, which may permit them to favor their own interests to the detriment of us and our unitholders.
 
Cheniere controls our general partner, which has sole responsibility for conducting our business and managing our operations. Some of our general partner’s directors are also directors of Cheniere, and certain of our general partner’s officers are officers of Cheniere. Therefore, conflicts of interest may arise between Cheniere and its affiliates, including our general partner, on the one hand, and us and our unitholders, on the other hand. In resolving these conflicts, our general partner may favor its own interests and the interests of its affiliates over the interests of us and our unitholders. These conflicts include, among others, the following situations:
 
 
•
neither our partnership agreement nor any other agreement requires Cheniere to pursue a business strategy that favors us. Cheniere’s directors and officers have a fiduciary duty to make these decisions in favor of the owners of Cheniere, which may be contrary to our interests:
 
 
•
our general partner controls the interpretation and enforcement of contractual obligations between us, on one hand, and Cheniere, on the other hand, including provisions governing administrative services and acquisitions;
 
 
•
our general partner is allowed to take into account the interests of parties other than us, such as Cheniere and its affiliates, in resolving conflicts of interest, which has the effect of limiting its fiduciary duty to us and our unitholders;
 
 
•
our general partner has limited its liability and reduced its fiduciary duties under the partnership agreement, while also restricting the remedies available to our unitholders for actions that, without these limitations, might constitute breaches of fiduciary duty;
 
 
•
Cheniere is not limited in its ability to compete with us. Please read “—Cheniere is not restricted from competing with us and is free to develop, operate and dispose of, and is currently developing, LNG receiving terminals, pipelines and other assets without any obligation to offer us the opportunity to develop or acquire those assets”;
 
 
•
our general partner determines the amount and timing of asset purchases and sales, capital expenditures, borrowings, issuances of additional partnership securities, and the establishment, increase or decrease in the amounts of reserves, each of which can affect the amount of cash that is distributed to our unitholders;
 
 
•
our general partner determines the amount and timing of any capital expenditures and whether a capital expenditure is a maintenance capital expenditure, which reduces operating surplus, or an expansion capital expenditure, which does not reduce operating surplus. This determination can affect the amount of cash that is distributed to our unitholders and the ability of the subordinated units to convert to common units;
 
 
16
 

 
•
our partnership agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered on terms that are fair and reasonable to us or entering into additional contractual arrangements with any of these entities on our behalf;
 
 
•
our general partner intends to limit its liability regarding our contractual and other obligations and, in some circumstances, is entitled to be indemnified by us;
 
 
•
our general partner may exercise its limited right to call and purchase common units if it and its affiliates own more than 80% of the common units; and
 
 
•
our general partner decides whether to retain separate counsel, accountants or others to perform services for us.
 
We expect that there will be additional agreements or arrangements with Cheniere and its affiliates, including future interconnection, natural gas balancing and storage agreements with one or more Cheniere-affiliated natural gas pipelines as well as other agreements and arrangements that cannot now be anticipated. In those circumstances where additional contracts with Cheniere and its affiliates may be necessary or desirable, additional conflicts of interest will be involved.
 
Cheniere is not restricted from competing with us and is free to develop, operate and dispose of, and is currently developing, LNG receiving terminals, pipelines and other assets without any obligation to offer us the opportunity to develop or acquire those assets.
 
Cheniere and its affiliates are not prohibited from owning assets or engaging in businesses that compete directly or indirectly with us. Cheniere may acquire, construct or dispose of its proposed Corpus Christi or Creole Trail LNG receiving terminals, its proposed pipelines or any other assets without any obligation to offer us the opportunity to purchase or construct any of those assets. In addition, under our partnership agreement, the doctrine of corporate opportunity, or any analogous doctrine, will not apply to Cheniere and its affiliates. As a result, neither Cheniere nor any of its affiliates will have any obligation to present new business opportunities to us, and they may take advantage of such opportunities themselves. Cheniere also has significantly greater resources and experience than we have, which may make it more difficult for us to compete with Cheniere and its affiliates with respect to commercial activities or acquisition candidates.
 
Our partnership agreement limits our general partner’s fiduciary duties to unitholders and restricts the remedies available to unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.
 
Our partnership agreement contains provisions that reduce the standards to which our general partner would otherwise be held by state fiduciary duty law. For example, our partnership agreement:
 
 
•
permits our general partner to make a number of decisions in its individual capacity, as opposed to in its capacity as our general partner. This entitles our general partner to consider only the interests and factors that it desires, and it has no duty or obligation to give any consideration to any interest of, or factors affecting, us, our affiliates or any limited partner. Examples include the exercise of its limited call right, the exercise of its rights to transfer or vote the units it owns, the exercise of its registration rights and its determination whether or not to consent to any merger or consolidation of the partnership or amendment to the partnership agreement;
 
 
•
provides that our general partner will not have any liability to us or our unitholders for decisions made in its capacity as general partner, as long as it acted in good faith, meaning that it believed the decision was in the best interests of our partnership;
 
 
•
generally provides that affiliated transactions and resolutions of conflicts of interest not approved by the conflicts committee of the board of directors of our general partner and not involving a vote of unitholders must be on terms no less favorable to us than those generally being provided to or available from unrelated third parties or be “fair and reasonable” to us and that, in determining whether a transaction or resolution is “fair and reasonable,” our general partner may consider the totality of the relationships between the parties involved, including other transactions that may be particularly favorable or advantageous to us;  
 
 
•
provides that our general partner, its affiliates and their officers and directors will not be liable for monetary damages to us or our limited partners for any acts or omissions unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that our general partner or those other persons acted in bad faith or engaged in fraud, willful misconduct or, in the case of a criminal matter, acted with knowledge that such conduct was criminal; and
 
 
•
provides that in resolving conflicts of interest, it will be presumed that in making its decision the conflicts committee or the general partner acted in good faith, and in any proceeding brought by or on behalf of any limited partner or us, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption.

 
17
 
 
    By purchasing a common unit, a unitholder will become bound by the provisions of our partnership agreement, including the provisions described above.
 
Holders of our common units have limited voting rights and are not entitled to elect our general partner or its directors, which could reduce the price at which the common units trade.
 
Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. Unitholders will have no right to elect our general partner or its board of directors on an annual or other continuing basis. The board of directors of our general partner is chosen entirely by Holdings. As a result, the price at which the common units will trade could be diminished because of the absence or reduction of a control premium in the trading price.
 
Even if unitholders are dissatisfied, they cannot initially remove our general partner without its consent.
 
Our unitholders are unable to remove our general partner without the consent of Cheniere Subsidiary Holdings, LLC, an affiliate of Cheniere, because Cheniere Subsidiary Holdings owns a sufficient number of subordinated units to be able to prevent removal of our general partner. The vote of the holders of at least 66 2/3% of all outstanding common and subordinated units (including any units owned by our general partner and its affiliates) voting together as a single class is required to remove our general partner. Cheniere Subsidiary Holdings owns approximately 82% of our outstanding common and subordinated units. In addition, if our general partner is removed without cause during the subordination period and units held by our general partner and its affiliates are not voted in favor of that removal, all remaining subordinated units will automatically be converted into common units and any existing arrearages on the common units will be extinguished. A removal of our general partner under these circumstances would adversely affect the common units by prematurely eliminating their distribution and liquidation preference over the subordinated units, which would otherwise have continued until we had met certain distribution and performance tests.
 
Cause is narrowly defined in our partnership agreement to mean that a court of competent jurisdiction has entered a final, non-appealable judgment finding our general partner liable for actual fraud or willful misconduct in its capacity as our general partner. Cause does not include most cases of poor management of the business, so the removal of the general partner because of the unitholder’s dissatisfaction with our general partner’s performance in managing our partnership will most likely result in the termination of the subordination period and conversion of all subordinated units to common units.
 
Control of our general partner may be transferred to a third party without unitholder consent.
 
Our general partner may transfer its general partner interest to a third-party in a merger or in a sale of all or substantially all of its assets without the consent of our unitholders. Furthermore, our partnership agreement does not restrict the ability of the owners of our general partner from transferring all or a portion of their respective ownership interest in our general partner to a third party. The new owners of our general partner would then be in a position to replace the board of directors and officers of our general partner with its own choices and thereby influence the decisions taken by the board of directors and officers.
 
Our general partner has a limited call right that may require our unitholders to sell their common units at an undesirable time or price.
 
An affiliate of our general partner owns 41.23% of our total common units. If the subordinated units convert into common units, affiliates of our general partner will own approximately 90.4% of the common units. If at any time more than 80% of our outstanding common units are owned by our general partner and its affiliates, our general partner will have the right, but not the obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of our common units held by unaffiliated persons at a price not less than their then-current market price, as defined in our partnership agreement. As a result, our unitholders may be required to sell their common units at an undesirable time or price and may not receive any return on their investment. Our unitholders may also incur a tax liability upon a sale of our common units. Our general partner is not obligated to obtain a fairness opinion regarding the value of the common units to be repurchased by it upon exercise of the limited call right. There is no restriction in our partnership agreement that prevents our general partner from issuing additional common units or other equity securities and exercising its call right. If our general partner exercised its limited call right, the effect would be to take us private and, if the common units were subsequently deregistered, we would no longer be subject to the reporting requirements of the Exchange Act.
 
Our partnership agreement restricts the voting rights of unitholders (other than our general partner and its affiliates) owning 20% or more of any class of our units.
 
Our partnership agreement restricts unitholders’ voting rights by providing that any units held by a person that owns 20% or more of any class of units then outstanding, other than our general partner and its affiliates, their transferees and persons who acquired
 

 
18
 
 
such units with the prior approval of the board of directors of our general partner, cannot vote on any matter. The partnership agreement also contains provisions limiting the ability of unitholders to call meetings or to acquire information about our operations, as well as other provisions limiting the unitholders’ ability to influence the manner or direction of management.
 
Our partnership agreement prohibits a unitholder (other than our general partner and its affiliates) who acquires 15% or more of our limited partner units without the approval of our general partner from engaging in a business combination with us for three years unless certain approvals are obtained. This provision could discourage a change of control that our unitholders may favor, which could negatively affect the price of our common units.
 
Our partnership agreement effectively adopts Section 203 of the Delaware General Corporation Law, or the DGCL. Section 203 of the DGCL as it applies to us prevents an interested unitholder, defined as a person (other than our general partner and its affiliates) who owns 15% or more of our outstanding limited partner units, from engaging in business combinations with us for three years following the time such person becomes an interested unitholder unless certain approvals are obtained. Section 203 broadly defines “business combination” to encompass a wide variety of transactions with or caused by an interested unitholder, including mergers, asset sales and other transactions in which the interested unitholder receives a benefit on other than a pro rata basis with other unitholders. This provision of our partnership agreement could have an anti-takeover effect with respect to transactions not approved in advance by our general partner, including discouraging takeover attempts that might result in a premium over the market price for our common units.
 
Our unitholders may not have limited liability if a court finds that unitholder action constitutes control of our business.
 
A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for contractual obligations of the partnership that are expressly made without recourse to the general partner. We are organized under Delaware law, and we conduct business in other states. As a limited partner in a partnership organized under Delaware law, holders of our common units could be held liable for our obligations to the same extent as a general partner if a court determined that the right or the exercise of the right by our unitholders as a group to remove or replace our general partner, to approve some amendments to the partnership agreement or to take other action under our partnership agreement constituted participation in the “control” of our business. In addition, limitations on the liability of holders of limited partner interests for the obligations of a limited partnership have not been clearly established in many jurisdictions.
 
Our unitholders may have liability to repay distributions wrongfully made.
 
Under certain circumstances, our unitholders may have to repay amounts wrongfully distributed to them. Under Section 17-607 of the Delaware Revised Uniform Limited Partnership Act, we may not make a distribution to our unitholders if the distribution would cause our liabilities to exceed the fair value of our assets. Delaware law provides that, for a period of three years from the date of the impermissible distribution, partners who received such a distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the partnership for the distribution amount. Liabilities to partners on account of their partner interests and liabilities that are non-recourse to the partnership are not counted for purposes of determining whether a distribution is permitted.
 
We may issue additional units without approval of our unitholders, which would dilute their ownership interest.
 
At any time during the subordination period, with the approval of the conflicts committee of the board of directors of our general partner, we may issue an unlimited number of limited partner interests of any type without the approval of our unitholders. After the subordination period, we may issue an unlimited number of limited partner interests of any type without limitation of any kind. The issuance by us of additional common units or other equity securities of equal or senior rank will have the following effects:
 
 
•
our unitholders’ proportionate ownership interest in us will decrease;
 
 
•
the amount of cash available per unit to pay distributions may decrease;  
 
 
•
because a lower percentage of total outstanding units will be subordinated units, the risk will increase that a shortfall in the payment of the initial quarterly distribution will be borne by our common unitholders;
 
 
•
the ratio of taxable income to distributions may increase;
 
 
•
the relative voting strength of each previously outstanding unit may be diminished; and
 
 
•
the market price of the common units may decline.
 

 
19
 
 
The price of our common units may fluctuate significantly, and our unitholders could lose all or part of their investment.
 
The market price of our common units may be influenced by many factors, some of which are beyond our control, including:
 
 
•
our quarterly distributions;
 
 
•
our quarterly or annual earnings or those of other companies in our industry;
 
 
•
actual or potential non-performance by any customer under a TUA;
 
 
•
announcements by us or our competitors of significant contracts;
 
 
•
changes in accounting standards, policies, guidance, interpretations or principles;
 
 
•
general economic conditions;
 
 
•
the failure of securities analysts to cover our common units or changes in financial or other estimates by analysts;
 
 
•
future sales of our common units; and
 
 
•
other factors described in these “Risk Factors.”
 
Affiliates of our general partner may sell common units, which sales could have an adverse impact on the trading price of the common units.
 
Sales by us or any of our existing unitholders, including Holdings, of a substantial number of our common units, or the perception that such sales might occur, could have a material adverse effect on the price of our common units or could impair our ability to obtain capital through an offering of equity securities. Affiliates of Cheniere own 10,891,357 common units and 135,383,831 subordinated units. All of the subordinated units will convert into common units at the end of the subordination period and may convert earlier. The sale of these units could have an adverse impact on the price of the common units.
 
Risks Relating to Tax Matters
 
Our tax treatment depends on our status as a partnership for federal income tax purposes, as well as our not being subject to a material amount of additional entity level taxation by individual states. If we were to be or become treated as a corporation for federal income tax purposes or if we were to become subject to a material amount of additional entity level taxation for state tax purposes, then our cash available for distribution to our unitholders would be substantially reduced.
 
The anticipated after-tax economic benefit of an investment in our common units depends largely on our being treated as a partnership for federal income tax purposes. We have not requested, and do not plan to request, a ruling from the Internal Revenue Service (“IRS”) on this matter.
 
If we were treated as a corporation for federal income tax purposes, we would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 35%, and we likely would pay state taxes as well. Distributions to our unitholders would generally be taxed again as corporate distributions, and no income, gains, losses or deductions would flow through to our unitholders. Because a tax would be imposed upon us as a corporation, the cash available for distributions to our unitholders would be substantially reduced. Therefore, treatment of us as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to our unitholders, likely causing a substantial reduction in the value of our common units.
 
Current law may change, causing us to be treated as a corporation for federal income tax purposes or otherwise subjecting us to a material amount of entity level taxation for federal, state or local income tax purposes. In addition, several states are evaluating ways to subject partnerships to entity level taxation through the imposition of state income, franchise or other forms of taxation. For example, we have become subject to a new entity level tax on the portion, if any, of our revenue generated in Texas beginning for tax reports due on or after January 1, 2008. Specifically, the Texas margin tax will be imposed at a maximum effective rate of 0.7% of our gross income apportioned to Texas. Imposition of such tax on us by the State of Texas, or any other state, will reduce the cash available for distribution to our unitholders.
 
The tax treatment of public traded partnerships or an investment in our common units could be subject to potential legislation, judicial or administrative changes and differing interpretations, possible on a retroactive basis.

The present U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative or judicial interpretation at any time.  Any modification to the U.S. federal income tax laws and interpretations thereof could make it more difficult or impossible to meet the exception for us to be treated as a
 
 
20
 

partnership for U.S. federal income tax purposes that is not taxable as a corporation, or Qualifying Income Exception, affect or cause us to change our business activities, affect the tax considerations of an investment in us, change the character or treatment of portions of our income and adversely affect an investment in our common units.  For example, in response to certain recent developments, members of Congress are considering substantive changes to the definition of qualifying income under Section 7704(d) of the Internal Revenue Code.  It is possible that these legislative efforts could result in changes to the existing U.S. tax laws that affect publicly traded partnerships, including us.  Any modification to the U.S. federal income tax laws and interpretations thereof may or may not be applied retroactively.  We are unable to predict whether any of these changes, or other proposals, will ultimately be enacted.  Any such changes could negatively impact the value of an investment in our common units.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our common units each month based upon the ownership of our common units on the fist day of each month, instead of on the basis of the date a particular common unit is transferred.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our common units each month based upon the ownership of our common units on the first business day of each month, instead of on the basis of the date a particular unit is transferred.  The use of this proration method may not be permitted under existing Treasury regulations, and, accordingly, our counsel is unable to opine as to the validity of this method.  If the IRS were to challenge this method or new Treasury regulations were issued, we may be required to change the allocation of items of income, gain, loss and deduction amount our unitholders.

A change in tax treatment of our partnership, or a successful IRS contest of the federal income tax positions that we take, may adversely impact the market for our common units, and the costs of any contests will be borne by our unitholders and our general partner.
 
The IRS may adopt positions that differ from the positions that we take, even positions taken with advice of counsel. It may be necessary to resort to administrative or court proceedings to sustain some or all of the positions that we take. A court may not agree with some or all of the positions that we take. Any contest with the IRS may materially and adversely impact the market for our common units and the price at which our common units trade. In addition, the costs of any contest with the IRS, principally legal, accounting and related fees, will result in a reduction in cash available for distribution to our unitholders and our general partner and thus will be borne indirectly by our unitholders and our general partner.
 
Our unitholders may be required to pay taxes on their share of our taxable income even if they do not receive any cash distributions from us.
 
Because our unitholders will be treated as partners to whom we will allocate taxable income, which could be different in amount from the cash that we distribute, our unitholders will be required to pay federal income taxes and, in some cases, state and local income taxes on their share of our taxable income even if they do not receive any cash distributions from us. Our unitholders may not receive cash distributions from us equal to their share of our taxable income or even equal to the actual tax liability which results from their share of our taxable income.
 
We intend to allocate items of income, gain, loss and deduction among the holders of our common units and subordinated units on or after the date that the subordination period ends to ensure that common units issued in exchange for our subordinated units have the same economic and federal income tax characteristics as our other common units. Any such allocation of items of our income or gain to unitholders, which may include allocations to holders of our common units, would not be accompanied by a distribution of cash to such unitholders. In addition, any such allocation of items of deduction or loss to specific unitholders (for example, to the holder of the subordinated units) would effectively reduce the amount of items of deduction or loss that will be allocated to other unitholders.
 
Tax gain or loss on the disposition of our common units could be different than expected.
 
If our unitholders sell common units, they will recognize gain or loss equal to the difference between the amount realized and their tax basis in those common units. Prior distributions to our unitholders in excess of the total net taxable income a unitholder is allocated for a common unit, which decreased their tax basis in that common unit, will, in effect, become taxable income to them if the common unit is sold at a price greater than their tax basis in that common unit, even if the price they receive is less than their original cost. A substantial portion of the amount realized, whether or not representing gain, may be ordinary income to our unitholders.
 
Tax-exempt entities face unique tax issues from owning common units that may result in adverse tax consequences to them.
 
Investments in common units by tax-exempt entities, such as individual retirement accounts (known as IRAs), raises issues unique to them. For example, virtually all of our income allocated to unitholders who are organizations exempt from federal income

 
21
 

tax, including individual retirement accounts and other retirement plans, will be unrelated business taxable income and will be taxable to them.
 
Non-U.S. investors face unique tax issues from owning common units that may result in adverse tax consequences to them.
 
Non-U.S. investors who own common units will be required to file United States federal income tax returns and pay tax on their share of our taxable income. Distributions to non-U.S. investors will generally be reduced by withholding taxes at the highest applicable effective tax rate (currently 35%) whether or not we have taxable income. The IRS has taken the position that a non-U.S. investor’s gain on the sale of common units is subject to United States federal income tax.
 
We will treat each holder of our common units as having the same tax benefits without regard to the actual common units held. The IRS may challenge this treatment, which could adversely affect the value of our common units.
 
Because we cannot match transferors and transferees of common units, we adopt depreciation and amortization positions that may not conform with all aspects of applicable Treasury regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to a common unitholder. It also could affect the timing of these tax benefits or the amount of gain from a sale of common units and could have a negative impact on the value of our common units or result in audit adjustments to the common unitholders’ tax returns.
 
Our unitholders will likely be subject to state and local taxes and return filing requirements as a result of an investment in our common units.
 
In addition to federal income taxes, our unitholders will likely be subject to other taxes, including state and local income taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we do business or own property. We will initially own property or do business in Louisiana and Texas. Our unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Furthermore, our unitholders may be subject to penalties for failure to comply with those requirements. We may own property or conduct business in other states or foreign countries in the future. It is the responsibility of our unitholders to file all United States federal, state and local tax returns.
 
The sale or exchange of 50% or more of our capital and profits interests during any twelve-month period will result in the termination of our partnership for federal income tax purposes.
 
We will be considered to have terminated for federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a twelve-month period. Our termination would, among other things, result in the closing of our taxable year for all unitholders and could result in a deferral of depreciation deductions allowable in computing our taxable income.

We may adopt certain valuation methodologies that may result in a shift of income, gain, loss and deduction between the general partner and the unitholders.  The IRS may challenge this treatment, which could adversely affect the value of the common units.
 
When we issue additional units or engage in certain other transactions, we will determine the fair market value of our assets and allocate any unrealized gain or loss attributable to our assets to the capital accounts of our unitholders and our general partner.  Our methodology may be viewed as understating the value of our assets.  In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and the general partner, which may be unfavorable to such unitholders.  Moreover, under our methodologies subsequent purchasers of common units may have a greater portion of their Internal Revenue Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets.  The IRS may challenge our methods, or our allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of income, gain, loss and deduction between the general partner and certain of our unitholders.

A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to our unitholders.  It also could affect the amount of gain from our unitholders’ sale of common units and could have a negative impact on the value of the common units or results in audit adjustments to our unitholders’ tax returns without benefit of additional deductions.
 

 
22
 

 ITEM 1B. UNRESOLVED STAFF COMMENTS
 
None.
 
ITEM 3. LEGAL PROCEEDINGS
 
We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. In the opinion of management, as of December 31, 2009, there were no threatened or pending legal matters that would have a material impact on our consolidated results of operations, financial position or cash flows.
 
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
 
None.
 
PART II
 
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED UNITHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
 
Our common units began trading on the NYSE Amex Equities (formally know as NYSE Alternext US) under the symbol “CQP” commencing with our initial public offering on March 21, 2007. The table below presents the high and low daily closing sales prices per common unit, as reported by the NYSE Amex Equities, and cash distributions to common unitholders for the period indicated.

   
High
    
Low
    
Cash Distributions
Per Unit (1)
  
Three Months Ended
                  
March 31, 2008
   $ 17.39     $ 14.85     $ 0.425  
June 30, 2008
     16.14       8.69       0.425  
September 30, 2008
     10.21       6.95       0.425  
December 31, 2008
     6.98       3.71       0.425  
                         
Three Months Ended
                        
March 31, 2009
     7.10       4.32       0.425  
June 30, 2009
     7.99       6.03       0.425  
September 30, 2009
     9.95       6.95       0.425  
December 31, 2009
     13.30       9.27       0.425  
 
(1)
We also paid cash distributions to subordinated unitholders and to our general partner with respect to its 2% general partner interest.
 
A distribution for the quarter ended December 31, 2009 of $0.425 per unit was paid on February 12, 2010.
 
As of February 17, 2010, we had 26,416,357 common units outstanding held by approximately 19 record owners.
 
We consider cash distributions to unitholders on a quarterly basis, although there is no assurance as to the future cash distributions since they are dependent upon future earnings, cash flows, capital requirements, financial condition and other factors. The Sabine Pass Indenture discussed in Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations”, may prohibit Sabine Pass LNG from making cash distributions to us under certain circumstances, which could limit our ability to make distributions.
 
Upon the closing of our initial public offering, Cheniere received 135,383,831 subordinated units. Below is a description of our cash distribution policy regarding common and subordinated units.
 
 Cash Distribution Policy

Our cash distribution policy is consistent with the terms of our partnership agreement, which requires that we distribute all of our available cash quarterly.

 
23
 
 
Subordination Period
 
During the subordination period, which commenced upon the closing of our initial public offering, the common units have the right to receive distributions of available cash from operating surplus in an amount equal to the initial quarterly distribution of $0.425 per quarter, plus any arrearages in the payment of the initial quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. Cheniere owns all of the subordinated units, representing 83.7% of the limited partner interests in us. These units are deemed “subordinated” because for a period of time, referred to as the subordination period, the subordinated units will not be entitled to receive any distributions until after the common units have received the initial quarterly distribution plus any arrearages from prior quarters. Furthermore, no arrearages will be paid on the subordinated units. The practical effect of the subordination period is to increase the likelihood that during this period there will be sufficient available cash to pay the initial quarterly distribution on the common units.
 
Definition of Subordination Period
 
The subordination period will extend until the first business day following the distribution of available cash to partners in respect of any quarter ending on or after June 30, 2010 that each of the following occurs:
 
 
•
distributions of available cash from operating surplus on each of the outstanding common units, subordinated units and general partner units equaled or exceeded the initial quarterly distribution for each of the three consecutive, non-overlapping four-quarter periods immediately preceding that date;
 
 
•
the adjusted operating surplus generated during each of the three consecutive, non-overlapping four-quarter periods immediately preceding that date equaled or exceeded the sum of the initial quarterly distributions on all of the outstanding common units, subordinated units and general partner units during those periods on a fully diluted basis; and
 
 
•
there are no arrearages in payment of the initial quarterly distribution on the common units.
 
Expiration of the Subordination Period
 
When the subordination period expires, each outstanding subordinated unit will convert into one common unit and will then participate pro rata with the other common units in distributions of available cash. In addition, if the unitholders remove our general partner other than for cause and units held by the general partner and its affiliates are not voted in favor of such removal:
 
 
•
the subordination period will end and each subordinated unit will immediately convert into one common unit;
 
 
•
any existing arrearages in payment of the initial quarterly distribution on the common units will be extinguished; and
 
 
•
the general partner will have the right to convert its general partner units and its incentive distribution rights into common units or to receive cash in exchange for those interests.
 
Early Conversion of Subordinated Units
 
The subordination period will automatically terminate and all of the subordinated units will convert into common units on a one-for-one basis on the first business day following the distribution of available cash to partners in respect of any quarter ending on or after June 30, 2008 that each of the following occurs:
 
 
•
distributions of available cash from operating surplus on each outstanding common unit, subordinated unit and general partner unit equaled or exceeded $2.55 (150% of the annualized initial quarterly distribution) for the four-quarter period immediately preceding that date;
 
 
•
the adjusted operating surplus generated during the four-quarter period immediately preceding that date equaled or exceeded the sum of a distribution of $2.55 (150% of the annualized initial quarterly distribution) on all of the outstanding common units, subordinated units and general partner units on a fully diluted basis; and
 
 
•
there are no arrearages in payment of the initial quarterly distribution on the common units.
 
General Partner Units and Incentive Distribution Rights
 
Incentive distribution rights represent the right to receive an increasing percentage of quarterly distributions of available cash from operating surplus after the initial quarterly distribution and the subsequent target distribution levels have been achieved. Our general partner currently holds all of our incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in our partnership agreement.

 
24
 
 
Assuming we do not issue any additional classes of units and our general partner maintains its 2% interest, if we have made distributions to our unitholders from operating surplus in an amount equal to the initial quarterly distribution for any quarter, assuming no arrearages, then we will distribute any additional available cash from operating surplus for that quarter among the unitholders and our general partner as follows:

 
Total Quarterly Distribution
Target Amount
  
Marginal Percentage
Interest Distributions
   
Common and Subordinated Unitholders
  
General Partner
Initial quarterly distribution
$0.425
  
98%
  
2%
First Target Distribution
Above $0.425 up to $0.489
  
98%
  
2%
Second Target Distribution
Above $0.489 up to $0.531
  
85%
  
15%
Third Target Distribution
Above $0.531 up to $0.638
  
75%
  
25%
Thereafter
Above $0.638
  
50%
  
50%
 

 
25
 

ITEM 6. SELECTED FINANCIAL DATA
 
The following tables set forth the selected financial data of our combined predecessor entities for the periods and at the dates indicated. Our combined predecessor entities refer to us and our wholly-owned subsidiaries, including Sabine Pass LNG.
 
The financial data should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations and our Consolidated Combined Financial Statements and Notes thereto included elsewhere in this report.
 
 
Cheniere Energy Partners, L.P.
  
Combined Predecessor Entities
  
 
December 31,
  
 
2009
  
2008
  
2007
  
2006
  
2005
  
 
(in thousands)
Statement of Operations Data:
                              
Revenues (including transactions with affiliates)
$
416,790
  
$
15,000
  
$
—  
 
$
—  
 
$
—  
 
Expenses (including transactions with affiliates)
  
88,870
    
32,141
    
12,516
    
10,277
    
4,719
  
Income (loss) from operations
  
327,920
    
(17,141
)
  
(12,516
)
  
(10,277
)
  
(4,719
)
Other income (expense) (1)
  
(141,008
)
  
(61,203
)
  
(36,436
)
  
(50,495
)
  
456
  
Net income (loss)
  
186,912
    
(78,344
)
  
(48,952
)
  
(60,772
)
  
(4,263
)
                               
Cash Flow Data:
                              
Cash flows provided by (used in) operating activities
  
234,311
    
(1,156
)
  
(640
)
  
(27,912
)
  
6,319
  
Cash flows provided by (used in) investing activities
  
92,146
    
(560
)
  
(74,776
)
  
(1,544,408
)
  
(246,337
)
Cash flows provided by (used in) financing activities
  
(208,922
)
  
1,710
    
75,422
    
1,572,222
    
218,201
  
 
 
Cheniere Energy Partners, L.P.
  
Combined Predecessor Entities
  
 
December 31,
  
 
2009
  
2008
  
2007
  
2006
  
2005
  
 
(in thousands)
Balance Sheet Data:
                              
Cash and cash equivalents
$
117,542 
 
$
7
  
$
13
  
$
7
  
$
5
  
Restricted cash and cash equivalents (current)
  
13,732
    
235,985
    
191,179
    
176,324
    
8,871
  
Non-current restricted cash and cash equivalents
  
82,394
    
137,984
    
453,843
    
982,613
    
—  
 
Non-current restricted U.S. Treasury securities
  
—
    
20,829
    
63,923
    
—  
   
—  
 
Property, plant and equipment, net
  
1,588,557
    
1,517,507
    
1,127,289
    
651,676
    
270,740
  
Total assets
  
1,859,473
    
1,978,835
    
1,904,978
    
1,858,114
    
309,139
  
Long-term debt
  
2,110,101
    
2,107,673
    
2,032,000
    
2,032,000
    
72,485
  
Long-term debt—related party
  
72,928
    
70,661
    
—  
   
—  
   
—  
 
Long-term debt—affiliate
  
—
    
2,372
    
645
    
—  
   
—  
 
Deferred revenue (long-term)
  
33,500
    
37,500
    
40,000
    
40,000
    
40,000
  
Deferred revenue—affiliate (long-term)
  
7,360
    
4,971
    
2,583
    
—  
   
—  
 

(1)
The year ended December 31, 2006 includes a $23.8 million loss related to the extinguishment of debt issuance costs and a $20.6 million derivative loss as a result of terminating interest rate swaps, both related to the termination of the Sabine Pass credit facility in November 2006.
 
 
 
26
 

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATION
 
Introduction
 
The following discussion and analysis presents management’s view of our business, financial condition and overall performance and should be read in conjunction with our consolidated financial statements and the accompanying notes. This information is intended to provide investors with an understanding of our past performance, current financial condition and outlook for the future. Our discussion and analysis includes the following subjects:
 
 
•
Overview of Business
 
 
•
Overview of Significant 2009 Events
 
 
•
Liquidity and Capital Resources
 
 
•
Contractual Obligations
 
 
•
Results of Operations
 
 
•
Off-Balance Sheet Arrangements
 
 
•
Summary of Critical Accounting Policies
 
 
•
Recent Accounting Standards
 
Overview of Business
 
We are a Delaware limited partnership formed by Cheniere. Through our wholly-owned subsidiary, Sabine Pass LNG, L.P. (“Sabine Pass LNG”), we own and operate the Sabine Pass LNG receiving terminal located in western Cameron Parish, Louisiana on the Sabine Pass Channel.
 
Following the achievement of commercial operability of the Sabine Pass LNG receiving terminal in September 2008, Sabine Pass LNG began receiving capacity reservation fee payments from Cheniere Marketing, LLC (“Cheniere Marketing”), a wholly-owned subsidiary of Cheniere, under its TUA. In December 2008, Cheniere Marketing began paying Sabine Pass LNG its monthly capacity reservation fee payment on a quarterly basis.  Sabine Pass LNG also began receiving capacity reservation fee payments from Total Gas and Power North America, Inc. (formerly known as Total LNG USA, Inc.) (“Total”) and Chevron U.S.A., Inc. (“Chevron”) under their TUAs in March 2009 and June 2009, respectively, when Total and Chevron made their first monthly capacity reservation fee payments.
 
LNG Receiving Terminal Business
 
The Sabine Pass LNG receiving terminal has regasification capacity of approximately 4.0 Bcf/d and five liquefied natural gas (“LNG”) storage tanks with an aggregate LNG storage capacity of approximately 16.9 Bcf along with two unloading docks capable of handling the largest LNG carriers currently being operated or built. Construction of the Sabine Pass LNG receiving terminal commenced in March 2005.  We achieved full operability with total sendout capacity of approximately 4.0 Bcf/d and storage capacity of approximately 16.9 Bcf during the third quarter of 2009.

In the second quarter of 2009, Sabine Pass LNG purchased Sabine Pass Tug Services, LLC (“Tug Services”), a wholly-owned subsidiary of Cheniere. As a result, Sabine Pass LNG acquired a lease (the “Tug Agreement”) for the use of tug boats and marine services at the Sabine Pass LNG receiving terminal (see Note 14—“Leases” for further information on the Tug Agreement). In connection with this acquisition, Tug Services entered into a Terminal Marine Services Agreement (the “Tug Sharing Agreement”) with our three TUA customers to provide their LNG cargo vessels with tug boat and marine services at the Sabine Pass LNG receiving terminal.


 
27
 

Overview of Significant 2009 Events
 
In 2009, we maintained commercial operability of the Sabine Pass LNG receiving terminal and continued to execute our strategy to complete construction of the Sabine Pass LNG receiving terminal and to generate steady and reliable revenues under Sabine Pass LNG’s long-term TUAs. The major events of 2009 include the following:

 
•
receipt of capacity reservation fee payments from Cheniere Marketing, Total and Chevron and successful unloading and processing of LNG for each customer;
 
 
•
purchase, transportation and successful unloading of an additional LNG commissioning cargo for the Sabine Pass LNG receiving terminal;
 
 
•
commencement of distributions to our subordinated unitholder; and
 
 
•
completed construction and achieved full operability of the Sabine Pass LNG receiving terminal with approximately 4.0 Bcf/d of total sendout capacity and five LNG storage tanks with approximately 16.9 Bcf of aggregate storage capacity.
 
Liquidity and Capital Resources
 
Cash and Cash Equivalents
 
As of December 31, 2009, we had $117.5 million of cash and cash equivalents and $96.1 million of restricted cash and cash equivalents.  Of this amount, $117.4 million of cash and cash equivalents was held in our subsidiary, Sabine Pass LNG. The restricted cash and cash equivalents of $96.1 million was held by Sabine Pass LNG to pay interest on the Senior Notes.
 
The foregoing funds are anticipated to be sufficient to fund the remaining accrued liabilities related to construction, operating expenditures and interest requirements. Regardless whether Sabine Pass LNG receives revenues from Cheniere Marketing (or Cheniere, as guarantor), Sabine Pass LNG expects to have sufficient cash flow from payments made under its Total and Chevron TUAs to allow it to meet its future operating expenditures and interest payment requirements until maturity of the 2013 Notes. In order for us to fund our operations and make distributions to our unitholders, we are dependent on the ability of Sabine Pass LNG to make distributions to us. Sabine Pass LNG must satisfy certain restrictions under the Sabine Pass Indenture governing the Sabine Pass Notes before being able to make distributions to us, which will require that Cheniere Marketing make a substantial portion of its TUA payments to Sabine Pass LNG. As described below, Cheniere Marketing has a limited operating history, limited capital and no credit. If Sabine Pass LNG is unable to make restricted cash distributions to us, then we will likely be unable to make our anticipated future quarterly cash distributions on our units. Under such circumstances and absent additional external funding, Cheniere Marketing and Cheniere would likely be unable to meet their ongoing TUA and guarantee obligations to Sabine Pass LNG.
 
Construction
 
Construction at the Sabine Pass LNG receiving terminal was substantially completed in the third quarter of 2009. As of December 31, 2009, we had completed construction and attained full operability of the Sabine Pass LNG receiving terminal (with approximately 4.0 Bcf/d of total sendout capacity and five LNG storage tanks with approximately 16.9 Bcf of aggregate storage capacity), and such was accomplished within our budget.
 
TUA Revenues
 
The entire approximately 4.0 Bcf/d of regasification capacity at the Sabine Pass LNG receiving terminal has been fully reserved under two 20-year, firm commitment TUAs with unaffiliated third parties, and a third TUA with Cheniere Marketing. Each of the three customers at the Sabine Pass LNG receiving terminal must make the full contracted amount of capacity reservation fee payments under its TUA whether or not it uses any of its reserved capacity. Capacity reservation fee TUA payments are made by the Sabine Pass LNG third-party customers as follows:
 
 
•
Total has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly capacity payments to Sabine Pass LNG aggregating approximately $125 million per year for 20 years that commenced on April 1, 2009. Total, S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions; and
 
 
•
Chevron has reserved approximately 1.0 Bcf/d of regasification capacity and has agreed to make monthly capacity payments to Sabine Pass LNG aggregating approximately $125 million per year for 20 years that commenced on July 1, 2009. Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.
 
    In addition, Cheniere Marketing has reserved the remaining 2.0 Bcf/d of regasification capacity and is entitled to use any capacity not utilized by Total and Chevron. Cheniere Marketing began making its TUA capacity reservation fee payments in the

 
 
28
 

fourth quarter of 2008.  Cheniere Marketing is required to make monthly capacity payments aggregating approximately $250 million per year for the period from January 1, 2009 through at least September 30, 2028.

Cheniere Marketing continues to develop its business, has a limited operating history, limited capital and lacks a credit rating.  Cheniere, which has guaranteed the obligations of Cheniere Marketing under its TUA, has a non-investment grade corporate rating.  In addition, the LNG and natural gas marketing business activities of Cheniere Marketing were downsized during 2008.  If Cheniere and its subsidiaries do not have sufficient liquidity to pay their obligations, including payments to us required under the Cheniere Marketing TUA, then Sabine Pass LNG will likely be unable to make restricted cash distributions to our partners under the Sabine Pass Indenture described below.  If Sabine Pass LNG is unable to make such restricted cash distributions, then we will likely be unable to make our anticipated future quarterly cash distributions on our units.  Under such circumstances and absent funding of a TUA reserve account, Cheniere Marketing and Cheniere would likely be unable to meet their TUA and guarantee obligations to Sabine Pass LNG.
 
Under each of these TUAs, Sabine Pass LNG is also entitled to retain 2% of the LNG delivered for the customer’s account, which Sabine Pass LNG will use primarily as fuel for revaporization and self-generated power at the Sabine Pass LNG receiving terminal.
 
Each of Total and Chevron previously paid Sabine Pass LNG $20.0 million in nonrefundable advance capacity reservation fees, which are being amortized over a 10-year period as a reduction of each customer’s regasification capacity reservation fees payable under its respective TUA.
 

 
29
 

Sources and Uses of Cash
 
The following table summarizes (in thousands) the sources and uses of our cash and cash equivalents for the years ended December 31, 2009, 2008 and 2007. The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, that are referred to elsewhere in this report. Additional discussion of these items follows the table:
 
 
Year Ended December 31,
  
 
2009
  
2008
  
2007
  
SOURCES OF CASH AND CASH EQUIVALENTS
                  
Use of restricted cash and cash equivalents
$
298,673
  
$
426,592
  
$
460,762
  
Operating cash flow
  
234,311
    
—  
   
—
  
Proceeds from issuance of debt
  
—
    
144,965   
   
—
  
Borrowings under long-term note—affiliate
  
114
    
1,708
    
645
  
Proceeds from issuance of common units
  
—
    
—
    
98,442
  
Affiliate payable
  
—
    
1
    
3
  
Total sources of cash and cash equivalents
  
533,098
    
573,266
    
559,852
  
USES OF CASH AND CASH EQUIVALENTS
                  
LNG receiving terminal construction-in-process
  
(96,918
)
  
(402,955
)
  
(430,405
)
Distributions to owners
  
(280,675
)
  
(45,824
)
  
(23,668
)
Advances under long-term contracts
  
(601
)
  
(14,274
)
  
(39,155
)
Repayment of long-term note—affiliate
  
(2,467
)
  
—
    
—
  
Advances to affiliate—LNG held for commissioning, net of amounts transferred to LNG receiving terminal construction-in-process
  
—
    
(9,923
)
  
—
  
Debt issuance costs
  
(23
)
  
(4,837
)
  
(725
)
Operating cash flow
  
—
    
(1,156
)
  
(640
)
Special rights adjustment
  
(34,879
)
  
—
    
—
  
Investments in restricted cash and cash equivalents
  
—
    
(94,303
)
  
—
  
Investment in restricted U.S. Treasury securities
  
—
    
—
    
(63,923
)
Other
  
—
    
—
    
(1,330
)
Total uses of cash and cash equivalents
  
(415,563
)
  
(573,272
)
  
(559,846
)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
  
117,535
    
(6
)
  
6
  
CASH AND CASH EQUIVALENTS—beginning of year
  
7
    
13
    
7
  
CASH AND CASH EQUIVALENTS—end of year
$
117,542
  
$
7
  
$
13
  
  
Use of restricted cash and cash equivalents
 
In 2009, 2008 and 2007, $298.7 million, $426.6 million and $460.8 million of restricted cash and cash equivalents, respectively, were primarily used to pay for scheduled interest payments and construction activities at the Sabine Pass LNG receiving terminal.  Under the Sabine Pass Indenture, a portion of the proceeds from the Senior Notes was initially required to be used for scheduled interest payments through May 2009 and to fund the cost to complete construction of the Sabine Pass LNG receiving terminal. Due to these restrictions imposed by the indenture, the proceeds are not presented as cash and cash equivalents, and therefore, when proceeds from the Senior Notes are used, they are presented as a source of cash and cash equivalents.  The decreased use of restricted cash and cash equivalents in 2008 and 2009 primarily resulted from completing construction of the initial sendout capacity of approximately 2.6 Bcf/d and storage capacity of approximately 10.1 Bcf at the Sabine Pass LNG receiving terminal in September 2008, and the substantial completion of the Sabine Pass LNG receiving terminal’s construction activities during the third quarter 2009.
 
Operating cash flow
 
In 2009, Sabine Pass LNG received capacity reservation fee payments from Cheniere Marketing of approximately $250 million, and received capacity reservation fee payments from Total and Chevron of approximately $177 million. These operating cash flows were offset by interest expense, operating and maintenance costs and general and administrative costs.

In September 2008, Sabine Pass LNG received $15.0 million from Cheniere Marketing related to prepaid capacity reservation fee payments for the last three months of 2008. In addition, Sabine Pass LNG received $62.7 million in December 2008 from Cheniere Marketing related to prepaid capacity reservation fee payments for the first three months of 2009. These operating cash flows were offset by interest expense, operating and maintenance costs and general and administrative costs.

 
30
 

Proceeds from issuance of debt
 
Proceeds from issuance of debt were $145.0 million in 2008. The $145.0 million borrowings during 2008 related to the additional issuance of 2016 Notes, net of discount.
 
Proceeds from issuance of common units
 
Proceeds from issuance of common units of $98.4 million relate to the 2007 issuance of 5.1 million of our common units at an initial public offering price of $21.00 per unit, net of underwriting discounts and commissions of $7.2 million and a structuring fee of $0.5 million. We used all of the net proceeds we received to purchase U.S. Treasury securities to fund a distribution reserve for payment of the initial quarterly distributions through the quarter ended June 30, 2009.
 
LNG receiving terminal construction-in-process, net
 
Capital expenditures for the Sabine Pass LNG receiving terminal were $96.9 million, $403.0 million and $430.4 million in 2009, 2008 and 2007, respectively. Our capital expenditures decreased in 2009 as a result of the substantial completion of the construction of the Sabine Pass LNG receiving terminal in the third quarter of 2009.  Our capital expenditures decreased in 2008 as a result of the winding down and completion of construction of the initial phases of the Sabine Pass LNG receiving terminal.
 
Distributions to owners
 
We made $280.7 million of distributions to our common and subordinated unitholders and to our general partner in 2009.  We made $45.8 million and $23.7 million of distributions to common unitholders and to our general partner in 2008 and 2007, respectively.
 
Advances under long-term contracts
 
Sabine Pass LNG entered into certain contracts and purchase agreements related to the construction of the Sabine Pass LNG receiving terminal that required Sabine Pass LNG to make payments to fund costs that will be incurred or equipment that will be received in the future. Advances made under long-term contracts on purchase commitments are carried at face value and transferred to property, plant, and equipment as the costs are incurred or equipment is received.  Advances under long-term contracts were $0.6 million, $14.3 million and $39.2 million at December 31, 2009, 2008 and 2007, respectively. The decrease in 2009 compared to 2008 resulted from substantially completing construction of the Sabine Pass LNG receiving terminal in the third quarter of 2009. During 2009, the Sabine Pass LNG receiving terminal received equipment that it had previously advanced payment for under long-term contracts.  The decrease in 2008 compared to 2007 resulted from Sabine Pass LNG nearing completion of construction of the initial sendout capacity of approximately 2.6 Bcf/d and storage capacity of approximately 10.1 Bcf at the Sabine Pass LNG receiving terminal. During 2008, the Sabine Pass LNG receiving terminal received equipment that it had previously advanced payment for under long-term contracts.
 
Advances to affiliate—LNG held for commissioning, net of amounts transferred to LNG receiving terminal construction-in-process
 
During 2008, we advanced $9.9 million for LNG commissioning cargoes, net of amounts transferred to LNG receiving terminal construction-in-process.
  
Special rights adjustment
 
In August 2009, we determined that we would not need the remaining balance in the distribution reserve account to make distributions because we had adequate available cash from Sabine Pass LNG. We therefore distributed the remaining balance of $34.9 million in the distribution reserve account to Cheniere pursuant to the terms of our partnership agreement.  This contractual distribution has been presented as a Special rights adjustment to the equity accounts of Cheniere’s ownership on our Consolidated Statement of Partners’ Capital (Deficit) as of December 31, 2009.

Investments in restricted cash and cash equivalents
 
Investments in restricted cash and cash equivalents were $94.3 million in 2008. Investments in restricted cash and cash equivalents are cash and cash equivalents that have been contractually restricted to be used for a specific purpose. The 2008 investments in restricted cash and cash equivalents were related to borrowings that were contractually restricted to be used in the construction of the Sabine Pass LNG receiving terminal, interest payments on the Senior Notes and establishment of a distribution reserve account pursuant to our partnership agreement.

 
31
 
 
Investment in restricted U.S. Treasury securities
 
Investment in restricted U.S. Treasury securities was $63.9 million in 2007.  Investments in restricted U.S. Treasury securities were contractually restricted to be used for a specific purpose.  We invested $63.9 million of the proceeds we received from our 2007 initial public offering to purchase U.S. Treasury securities that were contractually restricted to fund our distribution reserve account to be used for the payment of initial quarterly distributions through June 30, 2009.

Cash Distributions to Unitholders
 
We deposited all of the net proceeds that we received from our public offering into a distribution reserve in a separate account. The deposited amount was invested in U.S. Treasury securities maturing as to principal and interest at such times and in such amounts sufficient to pay the $0.425 initial quarterly distribution per common unit for all common units, as well as related distributions to our general partner, through the distribution made in respect of the quarter ended June 30, 2009. As provided under our partnership agreement, any amount remaining in the distribution reserve was to be distributed to Cheniere. We received sufficient cash from Sabine Pass LNG to make distributions to all of our unitholders for the quarter ended June 30, 2009 without withdrawing funds from the distribution reserve account. We therefore distributed $34.9 million to Cheniere from the distribution reserve account in August 2009 pursuant to the terms of our partnership agreement.
 
Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash (as defined in our partnership agreement). Our available cash is our cash on hand at the end of a quarter less the amount of any reserves established. All distributions paid to date have been made from operating surplus. The following provides a summary of distributions paid by us during the year ended December 31, 2009:
 
           
Total Distribution (in thousands)
Date Paid
  
Period Covered by Distribution
  
Distribution Per Unit
  
Common and General Partner Units
  
Subordinated Units
February 13, 2009
  
October 1 – December 31, 2008 
 
$
0.425 
 
$
12,630 
 
$
57,538 
May 15, 2009
  
January 1 – March 31, 2009 
   
0.425 
 
$
12,630 
 
$
57,538 
August 14, 2009
  
April 1 – June 30, 2009 
   
0.425 
 
$
12,630 
 
$
57,538 
November 13, 2009
  
July 1, 2009 – September 30, 2009 
   
0.425 
 
$
12,630 
 
$
57,538 
 
Pursuant to our partnership agreement, all of the subordinated units will convert into common units on a one-for-one basis on the first business day following the distribution of available cash to partners in respect of any quarter ending on or after June 30, 2010, when certain conditions that are defined in our partnership agreement are met.  Based on our current projections, the earliest we anticipate that our subordination period may end would be no sooner than the first business day after the distribution is made in respect of the quarter ending March 31, 2012.
 
Debt Agreements
 
Senior Notes
 
Sabine Pass LNG has issued an aggregate principal amount of $2,215.5 million of Senior Notes consisting of $550.0 million of 7¼% Senior Secured Notes due 2013 and $1,665.5 million of 7½% Senior Secured Notes due 2016. Interest on the Senior Notes is payable semi-annually in arrears on May 30 and November 30 of each year. The Senior Notes are secured on a first-priority basis by a security interest in all of Sabine Pass LNG’s equity interests and substantially all of its operating assets. Under the Sabine Pass Indenture governing the Senior Notes, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied: there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment of approximately $82.4 million. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass Indenture. During the year ended December 31, 2009, Sabine Pass LNG made distributions of $295.7 million to us after satisfying all the applicable conditions in the Sabine Pass Indenture.
 
Services Agreements
 
In February 2005, Sabine Pass LNG entered into a 20-year operation and maintenance agreement with a wholly-owned subsidiary of Cheniere pursuant to which we receive all necessary services required to construct, operate and maintain the Sabine Pass LNG receiving terminal. Prior to substantial completion of the Sabine Pass LNG receiving terminal, as defined in Sabine Pass LNG’s engineering, procurement and construction (“EPC”) contract with Bechtel Corporation (“Bechtel”), Sabine Pass LNG was required to pay a fixed monthly fee of $95,000 (indexed for inflation) under the agreement. The fixed monthly fee increased to $130,000 (indexed
  
 
32
 

for inflation) upon the achievement of substantial completion of the Sabine Pass LNG receiving terminal in March 2009, and the counterparty is entitled to a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between Sabine Pass LNG and the counterparty at the beginning of each operating year. In addition, Sabine Pass LNG is required to reimburse the counterparty for its operating expenses, which consist primarily of labor expenses.
 
In February 2005, Sabine Pass LNG entered into a 20-year management services agreement with its general partner, which is a wholly-owned subsidiary of us, pursuant to which its general partner was appointed to manage the construction and operation of the Sabine Pass LNG receiving terminal, excluding those matters provided for under the operation and maintenance agreement described in the paragraph above. In August 2008, the general partner of Sabine Pass LNG assigned all of its rights and obligations under the management services agreement to Cheniere LNG Terminals, Inc. (“Cheniere Terminals”), a wholly-owned subsidiary of Cheniere. Prior to substantial completion of the Sabine Pass LNG receiving terminal, as defined in Sabine Pass LNG’s EPC contract with Bechtel, Sabine Pass LNG was required to pay Cheniere Terminals a monthly fixed fee of $340,000 (indexed for inflation). With the achievement of substantial completion of the Sabine Pass LNG receiving terminal in March 2009, the monthly fixed fee increased to $520,000 (indexed for inflation).
 
In March 2007, we entered into a services agreement with Cheniere Terminals pursuant to which we pay Cheniere Terminals an annual administrative fee of $10.0 million (adjusted for inflation) for the provision of various general and administrative services for our benefit following the closing of our initial public offering. Payments under this services agreement commenced January 1, 2009. In addition, we reimburse Cheniere Terminals for its services in an amount equal to the sum of all out-of-pocket costs and expenses incurred by Cheniere Terminals that are directly related to our business or activities.
 
During 2009, 2008 and 2007, we paid an aggregate of $18.5 million, $5.2 million and $5.2 million, respectively, under the foregoing service agreements.
 
State Tax Sharing Agreement
 
In November 2006, Sabine Pass LNG entered into a state tax sharing agreement with Cheniere effective for tax returns first due on or after January 1, 2008. Under this agreement, Cheniere has agreed to prepare and file all Texas franchise tax returns which it and Sabine Pass LNG are required to file on a combined basis and to timely pay the combined tax liability. If Cheniere, in its sole discretion, demands payment, Sabine Pass LNG will pay to Cheniere an amount equal to the Texas franchise tax that Sabine Pass LNG would be required to pay if its Texas franchise tax liability were computed on a separate company basis. This agreement contains similar provisions for other state and local taxes that Cheniere and Sabine Pass LNG are required to file on a combined, consolidated or unitary basis.
 
 
33
 

Contractual Obligations
 
We are committed to make cash payments in the future pursuant to certain of our contracts. The following table summarizes certain contractual obligations in place as of December 31, 2009 (in thousands).

 
Payments Due for Years Ended December 31,
  
 
Total
  
2010
  
2011-
2012
  
2013-
2014
  
Thereafter
  
Operating lease obligations (1) (2)
$
274,533   
 
$
8,905   
 
$
17,810   
 
$
17,810   
 
$
230,008   
 
Long-term debt (excluding interest) (3)
  
2,215,500   
     
—
    
—
    
550,000   
   
1,665,500   
  
Service contracts—
                              
Affiliate O&M agreement (4)
  
23,660   
   
1,560   
   
3,120   
   
3,120   
   
15,860   
   
Affiliate Sabine Pass LNG MSA (4)
  
94,640   
   
6,240   
   
12,480   
   
12,480   
   
63,440   
 
Affiliate services agreement (4)
  
192,500   
   
10,000   
    
20,000   
   
20,000   
   
142,500   
 
Construction and purchase obligations (4)
  
7,408   
     
7,408   
   
—
    
—
    
—
  
Cooperative endeavor agreements (4)
  
17,171   
    
2,453   
     
4,906   
    
4,906   
   
4,906   
 
Other Obligation (5)
  
3,01   
   
979   
   
2,039   
   
—
    
—
  
Total
$
2,828,430   
 
$
37,545   
  
$
60,355   
 
$
608,316   
 
$
2,122,214   
 
 
(1)
A discussion of these obligations can be found in Note 14—“Leases” of our Consolidated Combined Financial Statements.
 
(2)
Minimum lease payments have not been reduced by a minimum sublease rental of $129.6 million due in the future under noncancelable tug boat subleases.
 
(3)
Based on the total debt balance, scheduled maturities and interest rates in effect at December 31, 2009, our cash payments for interest would be $164.8 million in 2010, $164.8 million in 2011, $164.8 million in 2012, $161.5 million in 2013, $124.9 million in 2014 and $239.3 million for the remaining years for a total of $1,020.1 million.  See Note 11—“Long-Term Debt (including related party”) of our Consolidated Combined Financial Statements.
 
(4)
A discussion of these obligations can be found in Note 13—“Related Party Transactions” to our Consolidated Combined Financial Statements.
 
(5)
Other obligation consists of LNG receiving terminal security services.
 
Results of Operations
 
Overall Operations
 
2009 vs. 2008
 
Our consolidated net income increased $265.2 million, from a $78.3 million net loss in 2008 to a $186.9 million net income in 2009. This $265.2 million increase in net income in 2009 resulted from the commencement of revenues under the Cheniere Marketing TUA beginning October 1, 2008, the Total TUA on April 1, 2009 and the Chevron TUA on July 1, 2009.

2008 vs. 2007
 
Our consolidated net loss increased $29.3 million, from a $49.0 million net loss in 2007 to a $78.3 million net loss in 2008. The $29.3 million increase in net loss in 2008 was primarily due to decreased interest income, increased depreciation expense, increased operating and maintenance expense and increased operating and maintenance expense-affiliate, which were partially offset by decreased interest expense and derivative gain.
 
LNG TUA Revenue
 
2009 vs. 2008
 
Our LNG TUA revenue increased $163.9 million, from zero in 2008 to $163.9 million in 2009.  This $163.9 million increase primarily resulted from the commencement of revenues under the Total TUA beginning on April 1, 2009 and the Chevron TUA beginning on July 1, 2009.

 
34
 

LNG TUA Revenue from Affiliate
 
2009 vs. 2008
 
Our LNG TUA revenue from affiliate increased $237.9 million, from $15.0 million in 2008 to $252.9 million in 2009. Cheniere Marketing is required to make capacity reservation fee payments aggregating approximately $250 million per year for the period from January 1, 2009, through at least September 30, 2028. Following the achievement of commercial operability of the Sabine Pass LNG receiving terminal in September 2008, Cheniere Marketing made a capacity payment of $15.0 million for October, November and December of 2008.

2008 vs. 2007
 
Our LNG TUA revenue from affiliate increased from zero in 2007 to $15.0 million in 2008. Following the achievement of commercial operability of the Sabine Pass LNG receiving terminal in September 2008, Cheniere Marketing made a capacity payment of $15.0 million for October, November and December of 2008. We did not have TUA revenue in 2007, as the Sabine Pass LNG receiving terminal was not yet completed.

Operating and Maintenance Expense (including Affiliate Expense)
 
2009 vs. 2008

Operating and maintenance expense (including affiliate expense) increased $21.0 million, from $11.5 million in 2008 to $32.5 million in 2009. This $21.0 million increase resulted from the achievement of commercial operability of the initial 2.6 Bcf/d of sendout capacity and 10.1 Bcf of storage capacity of the Sabine Pass LNG receiving terminal in the third quarter of 2008 and the substantial completion of construction and achievement of full operability of the Sabine Pass LNG receiving terminal with approximately 4.0 Bcf/d of total sendout capacity and five LNG storage tanks with approximately 16.9 Bcf of aggregate storage capacity in the third quarter of 2009.

2008 vs. 2007

Operating and maintenance expense (including affiliate expense) increased $11.5 million, from zero in 2007 to $11.5 million in 2008. This $11.5 million increase resulted from the achievement of commercial operability of the initial 2.6 Bcf/d of regassification capacity and the 10.1 Bcf of storage capacity in September 2008 and also included costs to repair damage caused by Hurricane Ike.
 
Depreciation Expense
 
2009 vs. 2008

Depreciation expense increased $24.7 million, from $8.0 million in 2008 to $32.7 million in 2009. This $24.7 million increase in depreciation expense was primarily related to beginning depreciation on the costs associated with the initial 2.6 Bcf/d of sendout capacity and 10.1 Bcf of storage capacity of the Sabine Pass LNG receiving terminal that was placed into service in the third quarter of 2008. In addition, depreciation expense increased in 2009 as a result of the substantial completion of construction and achievement of full operability of the Sabine Pass LNG receiving terminal with approximately 4.0 Bcf/d of total sendout capacity and five LNG storage tanks with approximately 16.9 Bcf of aggregate storage capacity in the third quarter of 2009.

2008 vs. 2007

Depreciation expense increased $8.0 million, from zero in 2007 to $8.0 million in 2008. This $8.0 million increase resulted from our having begun depreciating the Sabine Pass LNG receiving terminal’s initial 2.6 Bcf/d of regassification capacity and 10.1 Bcf of storage capacity commencing in the third quarter of 2008 when it achieved commercial operability.

General and Administrative Expense (including Affiliate Expense)
 
2009 vs. 2008

General and administrative expense (including affiliate expense) increased $13.3 million, from $10.3 million in 2008 to $23.6 million in 2009. This increase primarily related to an increase in the amount of service agreement charges due to the achievement of substantial completion of the Sabine Pass LNG receiving terminal in March 2009 and due to the commencement of the services agreement with Cheniere Terminals on January 1, 2009.

 
35
 

Interest Income
 
2009 vs. 2008
 
Interest income decreased $12.9 million, from $13.8 million in 2008 to $0.9 million in 2009. This decrease resulted from less restricted cash and cash equivalents invested and lower interest rates during 2009 compared to 2008.

2008 vs. 2007
 
Interest income decreased $38.4 million, from $52.2 million in 2007 to $13.8 million in 2008. This decrease resulted from less restricted cash and cash equivalents invested and lower interest rates during 2008 compared to 2007.
 
Interest Expense, net
 
2009 vs. 2008
 
Interest expense, net of amounts capitalized, increased $67.3 million, from $79.9 million in 2008 to $147.2 million in 2009. This increase in interest expense, net of amount capitalized, primarily resulted from the additional $183.5 million, before discount, of 2016 Notes issued in September 2008, and a decrease in interest expense subject to capitalization in 2009 compared to 2008 due to the costs associated with placing the initial 2.6 Bcf/d of sendout capacity and 10.1 Bcf of storage capacity of the Sabine Pass LNG receiving terminal into service in September 2008 and achievement of full operability of the Sabine Pass LNG receiving terminal with approximately 4.0 Bcf/d of total sendout capacity and five LNG storage tanks with approximately 16.9 Bcf of aggregate storage capacity in the third quarter of 2009.

2008 vs. 2007
 
Interest expense, net of amounts capitalized, decreased $8.8 million, from $88.7 million in 2007 to $79.9 million in 2008. This decrease in interest expense, net of amount capitalized, primarily resulted from an increase in construction costs and consequently an increase in capitalized interest in 2008 compared to 2007.
 
Derivative Gain
 
2008 vs. 2007
 
Derivative gain increased $4.7 million, from zero in 2007 to $4.7 million in 2008.  On behalf of Sabine Pass LNG, Cheniere Marketing entered into natural gas swaps to hedge the exposure to variability in expected future cash flows from sales of excess LNG purchased for commissioning and performance testing during 2008.
  
Off-Balance Sheet Arrangements
 
As of December 31, 2009, we had no “off-balance sheet arrangements” that may have a current or future material affect on our consolidated financial position or results of operations.
 
Summary of Critical Accounting 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 apply the accounting rules to the specific set of circumstances existing in our business. In preparing our consolidated combined financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”), we endeavor 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, expenditures for direct construction activities, major renewals and betterments are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred.
 
 
36
 
 
We capitalized interest and other related debt costs during the construction period of the Sabine Pass LNG receiving terminal. Upon commencement of operations, capitalized interest, as a component of the total cost, has been amortized over the estimated useful life of the asset.
 
Revenue Recognition
 
LNG regasification capacity reservation fees are recognized as revenue over the term of the respective TUAs. Advance capacity reservation fees are initially deferred and amortized over a 10-year period as a reduction of a customer’s regasification capacity reservation fees payable under its TUA.  The retained 2% of LNG delivered for each customer’s account at the Sabine Pass LNG receiving terminal is recognized as revenues as Sabine Pass LNG performs the services set forth in each customer’s TUA.
 
Cash Flow Hedges
 
We have used, and may in the future use, derivative instruments to limit our exposure to variability in expected future cash flows. Cash flow hedge transactions hedge the exposure to variability in expected future cash flows. In the case of cash flow hedges, the hedged item (the underlying risk) is generally unrecognized (i.e., not recorded on the consolidated 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, U.S. GAAP 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 other comprehensive income, to the extent that the hedge is effective. We assess, both at the inception of each hedge and on an on-going basis, whether the 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 of the cash flow hedges 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.

Use of Estimates
 
The preparation of consolidated combined financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make certain estimates and assumptions that affect the amounts reported in the consolidated combined financial statements and the accompanying notes. Actual results could differ from our estimates and assumptions used.
 
Items subject to estimates and assumptions include, but are not limited to, the carrying amount of property, plant and equipment. Actual results could differ significantly from those estimates.
 
Recent Accounting Standards
 
In April 2009, the Financial Accounting Standards Board (“FASB”) issued a staff position providing additional guidance on factors to consider in estimating fair value when there has been a significant decrease in market activity for a financial asset. The guidance was effective for interim and annual periods ending after June 15, 2009. The implementation of this standard did not have a material impact on our financial position, results of operations or cash flow.
 
In April 2009, the FASB issued a staff position requiring fair value disclosures in both interim as well as annual financial statements in order to provide more timely information about the effects of current market conditions on financial instruments. The guidance is effective for interim and annual periods ending after June 15, 2009. The implementation of this standard did not have a material impact on our financial position, results of operations or cash flow.
 
In May 2009, the FASB issued new requirements for reporting subsequent events. These requirements set forth the period after the balance sheet date during which management of a reporting entity should evaluate events or transactions that may occur for potential recognition or disclosure in the financial statements, the circumstances under which an entity should recognize events or transactions occurring after the balance sheet date in its financial statements, and disclosures that an entity should make about events or transactions that occurred after the balance sheet date. Disclosure of the date through which an entity has evaluated subsequent events and the basis for the date is also required. This disclosure should alert all users of financial statements that an entity has not evaluated subsequent events after the date set forth in the financial statements being presented. The Company started adhering to these requirements in the second quarter of 2009.
 
 
37
 
 
In June 2009, the FASB issued SFAS No. 168, FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles. SFAS No. 168 establishes the FASB Accounting Standards Codification (the “Codification”) as the single source of authoritative GAAP recognized by the FASB to be applied by nongovernmental entities. Rules and interpretive releases of the SEC under authority of federal securities laws are also sources of authoritative GAAP for SEC registrants. SFAS No. 168 and the Codification are effective for financial statements issued for interim and annual periods ending after September 15, 2009. As of July 1, 2009, the Codification supersedes all existing non-SEC accounting and reporting standards. We adopted this statement for the period ended September 30, 2009. The adoption of this statement did not have an impact on our financial position, results of operations or cash flow.
 
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
 
Cash Investments
 
We have cash investments that we manage based on internal investment guidelines that emphasize liquidity and preservation of capital. Such cash investments are stated at historical cost, which approximates fair market value on our consolidated balance sheet.
 
Marketing and Trading Commodity Price Risk
 
On behalf of Sabine Pass LNG, Cheniere Marketing has entered into exchange cleared NYMEX natural gas swaps entered into to hedge the exposure to variability in expected future cash flows related to commissioning cargoes purchased by Cheniere Marketing that were or are expected to be sold as part of the testing phase of the commissioning process and operations.  We use value at risk (“VaR”) and other methodologies for market risk measurement and control purposes.  The VaR is calculated using the Monte Carlo simulation method. At December 31, 2009 and 2008, the one-day VaR with a 95% confidence interval on our derivative positions was less than $0.1 million.

As of December 31, 2009, Cheniere Marketing, on behalf of Sabine Pass LNG, had entered into a total of 360,851 MMBtu of NYMEX natural gas swaps through February 2010, for which we will receive fixed prices of $4.903 to $6.158 per MMBtu.  At December 31, 2009, the value of the derivatives was an asset of $0.1 million.
 
 
38
 

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
 
INDEX TO FINANCIAL STATEMENTS
 
CHENIERE ENERGY PARTNERS, L.P.
 
40 
41 
43 
44 
45 
46 
47 
62 
 

 
39
 

MANAGEMENT’S REPORT TO THE UNITHOLDERS OF CHENIERE ENERGY PARTNERS, L.P.
 
Management’s Report on Internal Control Over Financial Reporting
 
As management, we are responsible for establishing and maintaining adequate internal control over financial reporting for Cheniere Energy Partners, L.P. (“Cheniere Partners”) and its subsidiaries. In order to evaluate the effectiveness of internal control over financial reporting, as required by Section 404 of the Sarbanes-Oxley Act of 2002, we have conducted an assessment, including testing using the criteria in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Cheniere Partners’ system of internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements and, even when determined to be effective, can only provide reasonable assurance with respect to financial statement preparation and presentation.
 
Based on our assessment, we have concluded that Cheniere Partners maintained effective internal control over financial reporting as of December 31, 2009, based on criteria in Internal Control—Integrated Framework issued by the COSO.

Cheniere Partners’ independent auditors, Ernst & Young LLP, have issued an audit report on Cheniere Partners’ internal control over financial reporting
 
Management’s Certifications
 
The certifications of Cheniere Partners’ Chief Executive Officer and Chief Financial Officer required by the Sarbanes-Oxley Act of 2002 have been included as Exhibits 31 and 32 in Cheniere Partners’ Form 10-K.
 
                                                                   
 Cheniere Energy Partners, L.P.
   
By:
Cheniere Energy Partners GP, LLC,
 
Its general partner
 
 
         
By:
/s/    CHARIF SOUKI        
  
By:
/s/ Meg A. Gentle 
 
Charif Souki
    
Meg A. Gentle
 
Chief Executive Officer
(Principal Executive Officer)
    
Chief Financial Officer
(Principal Financial and Accounting Officer)
 

 
40
 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
 
The Board of Directors of Cheniere Energy Partners GP, LLC, and
 
Unitholders of Cheniere Energy Partners, L.P.
 
We have audited the accompanying consolidated balance sheets of Cheniere Energy Partners, L.P. and subsidiaries as of December 31, 2009 and 2008, and the related consolidated combined statements of operations, partners’ and owners’ capital (deficit), and cash flows for each of the three years in the period ended December 31, 2009. Our audits also included the financial statement schedule listed in the Index at Item 15(a). These financial statements and schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements and schedule based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Cheniere Energy Partners, L.P. and subsidiaries at December 31, 2009 and 2008, and the consolidated results of their operations and their cash flows for each of the three years in the period ended December 31, 2009, in conformity with U.S. generally accepted accounting principles. Also, in our opinion, the related financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly in all material respects the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Cheniere Energy Partners, L.P.’s internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 25, 2010 expressed an unqualified opinion thereon.
 
 
 
/s/    ERNST & YOUNG LLP
ERNST & YOUNG LLP
 
 
 
Houston, Texas
February 25, 2010
 
41
 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
The Board of Directors of Cheniere Energy Partners, GP, LLC, and
Unitholders of Cheniere Energy Partners, L.P.
 
We have audited Cheniere Energy Partners, L. P. and subsidiaries’ internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria). Cheniere Energy Partners, L.P. and subsidiaries’ management is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, Cheniere Energy Partners, L.P. and subsidiaries maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Cheniere Energy Partners, L.P. and subsidiaries as of December 31, 2009 and 2008, and the related consolidated combined statements of operations, partners’ and owners’ capital (deficit), and cash flows for each of the three years in the period ended December 31, 2009 and our reported dated February 25, 2010 expressed an unqualified opinion thereon.
 
 
 
/s/    ERNST & YOUNG LLP
ERNST & YOUNG LLP
 
 
 
 
                                          
Houston, Texas
February 25, 2010

 
42
 

CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
CONSOLIDATED BALANCE SHEETS
(in thousands, except unit data)
 
   
December 31,
  
   
2009
    
2008
  
ASSETS
            
CURRENT ASSETS
            
Cash and cash equivalents
  
$
117,542
    
$
7
  
Restricted cash and cash equivalents
    
13,732
      
235,985
  
Accounts and interest receivable
    
5,037
      
2,087
  
Accounts receivable—affiliate
    
3,586
      
419
  
Advances to affiliate
    
5,358
      
2,198
  
Advances to affiliate—LNG inventory
    
1,319
      
—  
  
LNG inventory
    
1,521
      
—  
  
Prepaid expenses and other
    
4,836
      
5,407
  
Total current assets
    
152,931
      
246,103
  
                 
NON-CURRENT RESTRICTED CASH AND CASH EQUIVALENTS
    
82,394
      
137,984
  
NON-CURRENT RESTRICTED U.S. TREASURY SECURITIES
    
—  
      
20,829
  
PROPERTY, PLANT AND EQUIPMENT, NET
    
1,588,557
      
1,517,507
  
DEBT ISSUANCE COSTS, NET
    
26,953
      
30,748
  
ADVANCES UNDER LONG-TERM CONTRACTS
    
1,021
      
10,705
  
ADVANCES TO AFFILIATE—LNG HELD FOR COMMISSIONING
    
—  
      
9,923
  
OTHER
    
7,617
      
5,036
  
Total assets
  
$
1,859,473
    
$
1,978,835
  
                 
LIABILITIES AND PARTNERS’ DEFICIT
                
CURRENT LIABILITIES
                
Accounts payable
  
$
39
    
$
137
  
Accounts payable—affiliate
    
306
      
514
  
Accrued liabilities
    
22,181
      
40,926
  
Accrued liabilities—affiliate
    
3,095
      
184
  
Deferred revenue
    
26,456
      
2,500
  
Deferred revenue—affiliate
    
63,507
      
62,742
  
Total current liabilities
    
115,584
      
107,003
  
                 
LONG-TERM DEBT, NET OF DISCOUNT
    
2,110,101
      
2,107,673
  
LONG-TERM DEBT—RELATED PARTY, NET OF DISCOUNT
    
72,928
      
70,661
  
LONG-TERM DEBT—AFFILIATE
    
—  
      
2,372
  
DEFERRED REVENUE
    
33,500
      
37,500
  
DEFERRED REVENUE—AFFILIATE
    
7,360
      
4,971
  
OTHER NON-CURRENT LIABILITIES
    
327
      
340
  
                 
COMMITMENTS AND CONTINGENCIES
    
—  
      
—  
  
                 
PARTNERS’ DEFICIT
                
Common unitholders (26,416,357 units issued and outstanding at December 31, 2009 and 2008)
    
(41,494
)
    
(23,520
)
Subordinated unitholders (135,383,831 units issued and outstanding at December 31, 2009 and 2008)
    
(427,026
)
    
(318,994
)
General partner interest (2% interest with 3,302,045 units issued and outstanding at December 31, 2009 and 2008)
    
(11,807
)
    
(9,171
)
Total partners’ deficit
    
(480,327
)
    
(351,685
)
Total liabilities and partners’ deficit
  
$
1,859,473
    
$
1,978,835
  
 

See accompanying notes to consolidated combined financial statements.

 
43
 

CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
CONSOLIDATED COMBINED STATEMENTS OF OPERATIONS
(in thousands, except per unit data)

   
Year Ended December 31,
  
   
2009
    
2008
    
2007
  
REVENUES
                  
Revenues
   $ 163,862     $ —       $ —     
Revenues—affiliate
     252,928       15,000       —    
TOTAL REVENUE
     416,790       15,000       —    
                         
EXPENSES
                        
Operating and maintenance expense
     20,683       6,345       —    
Operating and maintenance expense—affiliate
     11,833       5,125       —    
Depreciation expense
     32,742       7,994       35  
Development expense
     —         1,184       1,542  
Development expense—affiliate
     —         1,158       3,943  
General and administrative expense
     3,722       4,843       2,716  
General and administrative expense—affiliate
     19,890       5,492       4,280  
TOTAL EXPENSES
     88,870       32,141       12,516  
INCOME (LOSS) FROM OPERATIONS
     327,920       (17,141 )     (12,516 )
                         
OTHER INCOME (EXPENSE)
                        
Interest income
     930       13,778       52,225  
Interest expense, net
     (147,201 )     (79,887 )     (88,661 )
Interest expense—affiliate
     (13 )     —         —    
Derivative gain, net
     5,277       4,653       —    
Other
     (1 )     253       —    
TOTAL OTHER EXPENSE
     (141,008 )     (61,203 )     (36,436 )
NET INCOME (LOSS)
   $ 186,912     $ (78,344 )   $ (48,952 )
                         
Less:
                        
Net loss through March 25, 2007
                     (12,128 )
                         
Net loss for partners from March 26, 2007 through December 31, 2007
                   $ (36,824 )
                         
Allocation of net income (loss):
                        
Limited partners’ interest
     183,174       (76,777 )     (36,088 )
General partner’s interest
     3,738       (1,567 )     (736 )
Net income (loss) for partners
   $ 186,912     $ (78,344 )   $ (36,824 )
                         
Basic and diluted net income (loss) per limited partner unit
   $ 1.13     $ (0.48 )   $ (0.23 )
Weighted average number of limited partner units outstanding used for basic and diluted net income (loss) per unit calculation:
                        
Common units
     26,416       26,416       26,416  
Subordinated units
     135,384       135,384       135,384  
 
 
See accompanying notes to consolidated combined financial statements.
 

 
44
 

CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
CONSOLIDATED COMBINED STATEMENTS OF PARTNERS’ AND
OWNERS’ CAPITAL (DEFICIT)
(in thousands)
 
   
Partners’/Owners’ Deficit
    
Common
Units
    
Subordinated Units
    
General
Partner
Units
    
Total
  
                               
Balance at December 31, 2006
   $ (253,338 )   $ —       $ —       $ —       $ (253,338 )
Net loss through March 25, 2007
     (12,128 )     —         —         —         (12,128 )
Balance at March 25, 2007
     (265,466 )     —         —         —         (265,466 )
                                         
Contribution of net deficit investment to unitholders
     265,466       (35,434 )     (224,556 )     (5,476 )     —    
Proceeds from initial public offering, net of issuance costs
     —         98,442       —         —         98,442  
Net loss from March 26, 2007 through December 31, 2007
     —         (5,892 )     (30,196 )     (736 )     (36,824 )
Distributions
     —         (23,193 )     —       (476 )     (23,669 )
Balance at December 31, 2007
     —         33,923       (254,752 )     (6,688 )     (227,517 )
                                         
Net loss
     —         (12,535 )     (64,242 )     (1,567 )     (78,344 )
Distributions
     —         (44,908 )     —         (916 )     (45,824 )
Balance at December 31, 2008
     —         (23,520 )     (318,994 )     (9,171 )     (351,685 )
                                         
Net income
     —         29,907       153,268       3,737       186,912  
Distributions
     —         (44,909 )     (230,153 )     (5,613 )     (280,675 )
Special rights adjustment
     —         (2,972 )     (31,147 )     (760 )     (34,879 )
Balance at December 31, 2009
   $ —       $ (41,494 )   $ (427,026 )   $ (11,807 )   $ (480,327 )
 
 
See accompanying notes to consolidated combined financial statements.

 
45
 

CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
CONSOLIDATED COMBINED STATEMENTS OF CASH FLOWS
(in thousands)
 
   
Year Ended December 31,
  
   
2009
    
2008
    
2007
  
CASH FLOWS FROM OPERATING ACTIVITIES
                  
Net income (loss)
   $ 186,912     $ (78,344 )   $ (48,952 )
Adjustments to reconcile net income (loss) to net cash used in operating activities:
                        
Depreciation
     32,742       7,994       35  
Amortization of debt discount
     4,695       1,369       —  
Amortization of debt issuance costs
     3,818       3,984       3,793  
Non-cash derivative (gain) loss
     1,106       (1,230 )     —  
Interest income on restricted cash and cash equivalents
     —         (16,210 )     (49,638 )
Use of (investment in) restricted cash and cash equivalents
     —         (1,932 )     103,043  
Changes in operating assets and liabilities:
                        
Accounts and interest receivable
     1,526       3,498       —    
Accounts receivable—affiliate
     (3,167 )     (419 )     —    
Accounts payable and accrued liabilities
     (11,517 )     21,973       (11,875 )
Accounts payable and accrued liabilities—affiliate
     2,685       (350 )     408  
Deferred revenue—affiliate
     765       65,130       2,583  
Deferred revenue
     19,955       —         —    
Advances to affiliate
     (3,160 )     (491 )     —    
Prepaid and other
     (2,049 )     (6,128 )     (37 )
NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES
     234,311       (1,156 )     (640 )
                         
CASH FLOWS FROM INVESTING ACTIVITIES
                        
Use of restricted cash and cash equivalents
     189,665       426,592       460,037  
LNG terminal construction-in-process
     (96,918 )     (402,955 )     (430,405 )
Advances under long-term contracts
     (601 )     (14,274 )     (39,155 )
Advances to affiliate—LNG held for commissioning, net of amounts transferred to LNG receiving terminal construction-in-process
     —         (9,923 )     —    
Investment in restricted U.S. Treasury securities
     —         —         (63,923 )
Other
     —         —         (1,330 )
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES
     92,146       (560 )     (74,776 )
                         
CASH FLOWS FROM FINANCING ACTIVITIES
                        
Distributions to owners
     (280,675 )     (45,824 )     (23,668 )
Use of (investment in) restricted cash and cash equivalents
     109,008       (94,303 )     725  
Special rights adjustment
     (34,879 )     —         —    
Repayment of long-term note—affiliate
     (2,467 )     —         —    
Borrowings under long-term note—affiliate
     114       1,708       645  
Debt issuance costs
     (23 )     (4,837 )     (725 )
Proceeds from issuance of Sabine Pass LNG notes
     —         144,965       —    
Proceeds from issuance of common units
     —         —         98,442  
Affiliate payable
     —         1       3  
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES
     (208,922 )     1,710       75,422  
                         
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
     117,535       (6 )     6  
CASH AND CASH EQUIVALENTS—beginning of year
     7       13       7  
CASH AND CASH EQUIVALENTS—end of year
   $ 117,542     $ 7     $ 13  
 

See accompanying notes to consolidated combined financial statements.

 
46
 

CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS
 
NOTE 1—NATURE OF OPERATIONS
 
Cheniere Energy Partners, L.P. (“Cheniere Partners”) is a publicly-held limited partnership. As of December 31, 2009, Cheniere Energy, Inc. (“Cheniere”) owned 90.6% of the limited partnership through its wholly-owned subsidiaries, Cheniere LNG Holdings, LLC (“Holdings”), Cheniere Common Units Holdings, LLC, Cheniere Subsidiary Holdings, LLC (“Subsidiary Holdings”) and Cheniere Energy Partners GP, LLC (the “General Partner”). Cheniere Partners is a Delaware limited partnership formed on November 21, 2006 to own and operate the Sabine Pass liquefied natural gas (“LNG”) receiving and regasification facility in western Cameron Parish, Louisiana on the Sabine Pass Channel (the “Sabine Pass LNG receiving terminal”). Cheniere Partners and Holdings, as a selling unitholder, completed an initial public offering (the “Cheniere Partners Offering”) of Cheniere Partners’ common units on March 26, 2007.
 
The following entities were included on a combined basis in the accompanying Consolidated Combined Financial Statements for periods prior to the Cheniere Partners Offering because they were entities under common control:
 
 
•
Cheniere Partners;
 
 
•
Cheniere Energy Investments, LLC (“Cheniere Investments”) is a Delaware limited liability company owned by Cheniere Partners and was formed on November 21, 2006 to hold 100% of the ownership interests in Sabine Pass GP and Sabine Pass LP;
 
 
•
Sabine Pass LNG-GP, Inc. (“Sabine Pass GP”) is a Delaware corporation that was owned by Holdings and was formed in 2004 to be the general partner of Sabine Pass LNG, L.P.;
 
 
•
Sabine Pass LNG-LP, LLC (“Sabine Pass LP”) is a Delaware limited liability company that was owned by Holdings and was formed in 2004 to be the limited partner of Sabine Pass LNG; and
 
 
•
Sabine Pass LNG, L.P. (“Sabine Pass LNG”) is a Delaware limited partnership formed with one general partner, Sabine Pass GP, and one limited partner, Sabine Pass LP, which owns the entire interest in the Sabine Pass LNG receiving terminal. The purpose of this limited partnership is to own and operate the Sabine Pass LNG receiving terminal.
 
At the closing of the Cheniere Partners Offering on March 26, 2007, the equity interests in Sabine Pass GP and Sabine Pass LP were contributed to Cheniere Investments, thereby resulting in Sabine Pass GP, Sabine Pass LP and Sabine Pass LNG becoming indirect, wholly-owned subsidiaries of Cheniere Partners. From and after the closing of the Cheniere Partners Offering, Cheniere Investments and these subsidiaries are consolidated with Cheniere Partners in the accompanying consolidated combined financial statements. As used in these Notes to Consolidated Combined Financial Statements, the terms “Cheniere Partners”, “we”, “us” and “our” refer to Cheniere Partners and its consolidated subsidiaries effective with the closing of the Cheniere Partners Offering and the foregoing entities on a combined basis (the “Combined Predecessor Entities”) prior to the closing of the Cheniere Partners Offering, unless otherwise stated or indicated by context.
 
In the second quarter of 2009, Sabine Pass LNG purchased Sabine Pass Tug Services, LLC (“Tug Services”), a wholly-owned subsidiary of Cheniere.  As a result, we acquired a lease (the “Tug Agreement”) for the use of tug boats and marine services at the Sabine Pass LNG receiving terminal (see Note 14—“Leases”).  In connection with the acquisition, Tug Services entered into a Terminal Marine Services Agreement (the “Tug Sharing Agreement”) with Sabine Pass LNG’s three terminal use agreement (“TUA”) customers to provide their LNG cargo vessels with tug boat and marine services at the Sabine Pass LNG receiving terminal (see Note 14—“Leases”).
 
With the exception of Sabine Pass GP, we are not subject to either federal or state income tax, as the partners are taxed individually on their proportionate share of our earnings. Sabine Pass GP is a corporation and is subject to both federal and state income tax. However, since Sabine Pass GP’s inception, its activities have been strictly limited to holding a non-income or loss bearing general partner interest in Sabine Pass LNG and, thus, this entity has not realized any taxable net income to date and is not expected to realize any taxable net income in the future.

We have evaluated subsequent events through February 25, 2010.
 
 
47
 
CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 

NOTE 2—INITIAL PUBLIC OFFERING
 
We and Holdings, as a selling unitholder, completed an offering of 13,500,000 Cheniere Partners common units for $21.00 per common unit on March 26, 2007. We received $98.4 million of net proceeds, after deducting the underwriting discount and structuring fee, upon issuance of 5,054,164 common units to the public in the Cheniere Partners Offering. Holdings received $164.5 million of net proceeds, after deducting the underwriting discount and structuring fee, upon its sale of 8,445,836 common units. We did not receive any proceeds from the sale of common units by Holdings. Our common units are traded on the NYSE Alternext US under the symbol “CQP.”
 
Upon the closing of the Cheniere Partners Offering on March 26, 2007, the following transactions occurred:
 
 
•
Holdings contributed through us to our wholly-owned subsidiary, Cheniere Investments, all of its equity interests in Sabine Pass GP and Sabine Pass LP, which own all of the equity interests in Sabine Pass LNG;
 
 
•
we issued to Holdings 21,362,193 common units and 135,383,831 subordinated units;
 
 
•
we issued to our general partner, a direct wholly-owned subsidiary of Holdings, 3,302,045 general partner units representing a 2% general partner interest in us and all of our incentive distribution rights, which will entitle our general partner to increasing percentages of the cash that we distribute in excess of $0.489 per unit per quarter;
 
 
•
we issued 5,054,164 common units to the public in the Cheniere Partners Offering;
 
 
•
Holdings sold 8,445,836 common units to the public in the Cheniere Partners Offering, after which Holdings and the public held an aggregate 89.8% and 8.2% limited partner interest in us, respectively;
 
 
•
our general partner entered into a services agreement with an affiliate of Cheniere under which the affiliate provides various general and administrative services for an annual administrative fee of $10.0 million (adjusted for inflation after January 1, 2007), with payment having commenced January 1, 2009; and
 
 
•
we entered into a services and secondment agreement with an affiliate of Cheniere pursuant to which certain employees of the Cheniere affiliate have been seconded to our general partner to provide operating and routine maintenance services with respect to the Sabine Pass LNG receiving terminal.
 
We used all of our net proceeds of $98.4 million from the sale of our common units in the Cheniere Partners Offering to purchase U.S. Treasury securities that funded a distribution reserve for payment of initial quarterly distributions of $0.425 per common unit, as well as related quarterly distributions to our general partner, through the quarterly distribution made in respect of the quarter ended June 30, 2009.
 
NOTE 3—SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 
Basis of Presentation
 
Our Consolidated Combined Financial Statements were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). Certain items in the consolidated combined financial statements have been reclassified to conform to the current presentation.
 
Cash and Cash Equivalents
 
We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
 
Accounting for LNG Activities
 
Generally, expenditures for direct construction activities, major renewals and betterments are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred.

 
48
 
CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
We capitalized interest and other related debt costs during the construction period of the Sabine Pass LNG receiving terminal. Upon commencement of operations, capitalized interest, as a component of the total cost, has been amortized over the estimated useful life of the asset.
 
Advances to Affiliate-LNG Held for Commissioning
 
In connection with the construction of the Sabine Pass LNG receiving terminal, we required LNG to perform certain commissioning activities.  LNG purchased on behalf of Sabine Pass LNG by Cheniere Marketing has been funded by Sabine Pass LNG and is recorded at historical cost and classified as a non-current asset on our Consolidated Balance Sheets as advances to affiliate—LNG held for commissioning (See Note 13—“Related Party Transactions”); for this LNG, Cheniere Marketing holds title to the LNG at all times, sells all regasified LNG and remits the net proceeds from such sales back to Sabine Pass LNG. The LNG used in the commissioning process is capitalized net of amounts received from the sale of natural gas.
 
Revenue Recognition
 
LNG regasification capacity reservation fees are recognized as revenue over the term of the respective TUAs. Advance payments of capacity reservation fees are initially deferred and recognized into revenue, which are being amortized over a 10-year period as a reduction of each customer’s regasification capacity reservation fees payable under its TUA. For a discussion of potential revenue from related parties, please read Note 13—“Related Party Transactions.”  The retained 2% of LNG delivered for each customer’s account at the Sabine Pass LNG receiving terminal is recognized as revenues as Sabine Pass LNG performs the services set forth in each customer’s TUA.
 
Debt Issuance Costs
 
Debt issuance costs consist primarily of fees incurred that are directly related to the issuance of the Senior Notes (See Note 11—“Long-Term Debt (including related party)”). These costs are capitalized and are being amortized to interest expense over the terms of the Senior Notes.
 
Income Taxes
 
With the exception of Sabine Pass GP, the Combined Predecessor Entities are not subject to either federal or state income taxes, as the partners are taxed individually on their proportionate share of our earnings. Sabine Pass GP is a corporation and is subject to both federal and state income tax. However, since Sabine Pass GP’s inception, its activities have been strictly limited to holding a non-income or loss bearing general partner interest in Sabine Pass LNG, and thus, this entity has not realized any taxable net income to date and is not expected to realize any taxable net income in the future. At December 31, 2009, the tax basis of our assets and liabilities was $198.2 million greater than the reported amounts of our assets and liabilities.
 
Pursuant to the Sabine Pass Indenture, Sabine Pass LNG is permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which Sabine Pass LNG is a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The permitted Tax Distributions are equal to the tax that Sabine Pass LNG would owe if Sabine Pass LNG were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the State Tax Sharing Agreement discussed immediately below. The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by Sabine Pass LNG within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.
 
In November 2006, Sabine Pass LNG and Cheniere entered into a state franchise tax sharing agreement (the “State Tax Sharing Agreement”) pursuant to which Cheniere has agreed to prepare and file all Texas franchise tax returns which Sabine Pass LNG and Cheniere are required to file on a combined basis and to timely pay the combined Texas franchise tax liability. If Cheniere, in its sole discretion, demands payment, then Sabine Pass LNG will pay to Cheniere an amount equal to the Texas franchise tax that Sabine Pass LNG would be required to pay if its Texas franchise tax liability were computed on a separate company basis. The State Tax Sharing Agreement contains similar provisions for other state and local taxes required to be filed by Cheniere and Sabine Pass LNG on a combined, consolidated or unitary basis. The State Tax Sharing Agreement is effective for tax returns first due on or after January 1, 2008.

 
49
 
CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
Concentration of Credit Risk
 
Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date.
 
Sabine Pass LNG has entered into certain long-term TUAs with unaffiliated third parties for regasification capacity at our Sabine Pass LNG receiving terminal. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective TUAs. We have mitigated this credit risk by securing TUAs for a significant portion of our regasification capacity with creditworthy third-party customers with a minimum Standard & Poor’s rating of AA.
 
Property, Plant and Equipment
 
Property, plant and equipment are recorded at cost. Expenditures for construction activities, major renewals and betterments are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We began depreciating equipment and facilities associated with the initial 2.6 Bcf/d of sendout capacity and 10.1 Bcf of storage capacity of the Sabine Pass LNG receiving terminal when they were ready for use in the third quarter of 2008. We began depreciating equipment and facilities associated with the remaining 1.4 Bcf/d of sendout capacity and 6.8 Bcf of storage capacity of the Sabine Pass LNG receiving terminal when they were ready for use in the third quarter of 2009. The Sabine Pass LNG receiving terminal is depreciated using the straight-line depreciation method applied to groups of LNG receiving terminal assets with varying useful lives. The identifiable components of the Sabine Pass LNG receiving terminal with similar estimated useful lives have a depreciable range between 15 and 50 years. Depreciation of computer and office equipment, computer software, leasehold improvements and vehicles is computed using the straight-line method over the estimated useful lives of the assets, which range from two to ten years. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in operations.
 
Management reviews property, plant and equipment for impairment periodically and whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. No such impairment was recorded for December 31, 2009, 2008 or 2007.
 
Asset Retirement Costs
 
We recognize asset retirement obligations (“AROs”) for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset.

Based on the real property lease agreement at the Sabine Pass LNG receiving terminal, at the expiration of the term of the lease we are required to surrender the LNG receiving terminal in good working order and repair, with normal wear and tear and casualty expected. The property lease agreement at the Sabine Pass LNG receiving terminal has a term of up to 90 years including renewal options. Due to the language in the real property lease agreement, we have determined that the cost to surrender the LNG receiving terminal in the required condition will be minimal, and therefore have not recorded an ARO associated with the Sabine Pass LNG receiving terminal.
 
Cash Flow Hedges
 
We have used, and may in the future use, derivative instruments to limit our exposure to variability in expected future cash flows. Cash flow hedge transactions hedge the exposure to variability in expected future cash flows. 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 

 
50
 
CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 

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, U.S. GAAP 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 other comprehensive income, to the extent that the hedge is effective. We assess, both at the inception of each hedge and on an on-going basis, whether the 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 of the cash flow hedges 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.
 
Use of Estimates
 
The preparation of consolidated combined financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make certain estimates and assumptions that affect the amounts reported in the consolidated combined financial statements and the accompanying notes. Actual results could differ from our estimates and assumptions used.
 
Items subject to estimates and assumptions include, but are not limited to, the carrying amount of property, plant and equipment. Actual results could differ significantly from those estimates.

NOTE 4—RESTRICTED CASH AND CASH EQUIVALENTS
 
Restricted cash and cash equivalents and U.S. Treasury securities are comprised of cash that has been contractually restricted as to usage or withdrawal, as follows:
 
Sabine Pass LNG Receiving Terminal Construction Reserve
 
In November 2006, Sabine Pass LNG issued an aggregate principal amount of $2,032.0 million of Senior Secured Notes consisting of $550.0 million of 7¼% Senior Secured Notes due 2013 (the “2013 Notes”) and $1,482.0 million of 7½% Senior Secured Notes due 2016 (the “2016 Notes” and collectively with the 2013 Notes, the “Senior Notes”). In September 2008, Sabine Pass LNG issued an additional $183.5 million, before discount, of 2016 Notes whose terms were identical to the previously outstanding 2016 Notes. The additional issuance and the previously outstanding 2016 Notes are treated as a single series of notes under the indenture governing the Senior Notes (“Sabine Pass Indenture”) (See Note 11—“Long-Term Debt (including related party)”). Under the terms and conditions of the Senior Notes, Sabine Pass LNG was required to fund a cash reserve account for approximately $987 million to pay the remaining costs to complete construction of the Sabine Pass LNG receiving terminal. The cash accounts are controlled by a collateral trustee, and therefore, are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets. As of December 31, 2009, the Sabine Pass LNG receiving terminal construction reserve account balance was zero. As of December 31, 2008, the Sabine Pass LNG receiving terminal construction reserve account balance was $71.1 million, of which $27.4 million of the construction reserve account related to accrued construction costs that had been classified as part of current restricted cash and cash equivalents, and $43.7 million of the construction reserve account related to remaining construction costs had been classified as a non-current asset on our Consolidated Balance Sheets.
 
Senior Notes Debt Service Reserve
 
As described above, Sabine Pass LNG consummated private offerings of an aggregate principal amount of $2,215.5 million of Senior Notes (See Note 11—“Long-Term Debt (including related party)”). Under the Sabine Pass Indenture governing the Senior Notes, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied: there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment of approximately $82.4 million. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass Indenture. As of December 31, 2009 and 2008, we classified $13.7 million as current restricted cash and cash equivalents for the payment of interest due within twelve months. As of December 31, 2009 and 2008, we classified the permanent debt service reserve fund of $82.4 million as non-current restricted cash and cash equivalents. These cash accounts are controlled by a collateral trustee, and therefore, are shown as restricted cash and cash equivalents on our Consolidated Balance Sheets.
 
 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
Distribution Reserve
 
At the closing of our initial public offering, we funded a distribution reserve of $98.4 million, which was invested in U.S. Treasury securities. The distribution reserve, including interest earned thereon, was available to 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 the distribution made in respect of the quarter ended 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.
 
In August 2009, we determined that we would not need the remaining balance in the distribution reserve account to make distributions because we had adequate available cash from Sabine Pass LNG. We therefore distributed the remaining balance of $34.9 million in the distribution reserve account to Cheniere pursuant to the terms of our partnership agreement.  This contractual distribution has been presented as a Special rights adjustment to the equity accounts of Cheniere’s ownership on our Consolidated Combined Statement of Partners’ Capital (Deficit) as of December 31, 2009.
 
As of December 31, 2009 and 2008, we classified $0.1 million and zero as current restricted cash and cash equivalents that may be utilized to pay quarterly distributions.  As of December 31, 2009 and 2008, we classified zero and $12.0 million as non-current restricted cash that may be utilized to pay quarterly distributions, respectively. In addition, as of December 31, 2009 and 2008, we classified zero and $20.8 million as non-current restricted U.S. Treasury securities on our Consolidated Balance Sheets that may be utilized to pay quarterly distributions, as these securities had original maturities greater than three months.
 
NOTE 5—ADVANCES UNDER LONG-TERM CONTRACTS
 
We entered into certain EPC contracts and purchase agreements related to the construction of the Sabine Pass LNG receiving terminal that require us to make payments to fund costs that will be incurred or equipment that will be received in the future. Advances made under long-term contracts on purchase commitments are carried at face value and transferred to property, plant and equipment as the costs are incurred or equipment is received. As of December 31, 2009 and 2008, our advances under long-term contracts were $1.0 million and $10.7 million, respectively.
 

 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 

NOTE 6—PROPERTY, PLANT AND EQUIPMENT
 
Property, plant and equipment consists of LNG terminal costs, LNG site and related costs and fixed assets, as follows (in thousands):

   
December 31,
  
   
2009
    
2008
  
LNG TERMINAL COSTS
            
LNG receiving terminal
   $ 1,627,564     $ 919,776  
LNG receiving terminal construction-in-process
     —         604,398  
LNG site and related costs, net
     176       183  
Accumulated depreciation
     (39,975 )     (7,752 )
Total LNG receiving terminal costs
     1,587,765       1,516,605  
FIXED ASSETS
                
Computer and office equipment
     259       200  
Vehicles
     421       421  
Machinery and equipment
     931       751  
Other
     419       254  
Accumulated depreciation
     (1,238 )     (724 )
Total fixed assets, net
     792       902  
PROPERTY, PLANT AND EQUIPMENT, NET
   $ 1,588,557     $ 1,517,507  
 
As of December 31, 2009, the Sabine Pass LNG receiving terminal had been placed into service, and all costs associated with the construction of the Sabine Pass LNG receiving terminal are presented in the table above as LNG receiving terminal. For 2009, 2008 and 2007, we capitalized $26.1 million, $80.7 million and $66.2 million, respectively, of interest expense related to the construction of the Sabine Pass LNG receiving terminal.
 
We began depreciating equipment and facilities associated with the initial 2.6 Bcf/d of sendout capacity and 10.1 Bcf of storage capacity of the Sabine Pass LNG receiving terminal when they were ready for use in the third quarter of 2008. We began depreciating equipment and facilities associated with the remaining 1.4 Bcf/d of sendout capacity and 6.8 Bcf of storage capacity of the Sabine Pass LNG receiving terminal when they were ready for use in the third quarter of 2009. The Sabine Pass LNG receiving terminal is depreciated using the straight-line depreciation method applied to groups of LNG receiving terminal assets with varying useful lives. The identifiable components of the Sabine Pass LNG receiving terminal with similar estimated useful lives have a depreciable range between 15 and 50 years, as follows:

Components
  
Useful life (yrs)
  
LNG storage tanks
     50  
Marine berth, electrical, facility and roads
     35  
Regassification processing equipment (recondensers, vaporization and vents)
     30  
Sendout pumps
     20  
Others
     15-30  
 
Our ARO assessment is based on the real property lease agreements for the Sabine Pass LNG receiving terminal site.  At the expiration of the term of the leases, we are required to surrender the Sabine Pass LNG receiving terminal in good working order and repair, with normal wear and tear and casualty expected. Sabine Pass LNG’s property lease agreements have a term of up to 90 years including renewal options. Due to the language in the real property lease agreements, we have determined that the cost to surrender the Sabine Pass LNG receiving terminal in the required condition will be minimal, and therefore have not recorded an ARO associated with the Sabine Pass LNG receiving terminal.
 
NOTE 7—DEBT ISSUANCE COSTS
 
We have incurred debt issuance costs in connection with our long-term debt. These costs are capitalized and are being amortized over the term of the related debt. The amortization of the debt issuance cost was recorded as interest expense and subsequently capitalized as construction-in-process during the construction period of the Sabine Pass LNG receiving terminal. As of December 31,

 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
 2009 and 2008, we had capitalized $27.0 million and $30.7 million (net of accumulated amortization of $12.5 million and $8.6 million), respectively, of costs directly associated with the Senior Notes, as follows (in thousands):
 
As of December 31, 2009:

Long-Term Debt
    
Debt Issuance Costs
  
Amortization Period
    
Accumulated
Amortization
    
Net Costs
  
2013 Notes
  
$
9,353
  
7 years
  
$
(3,993
)
$
5,360
  
2016 Notes
    
30,057
  
10 years
    
(8,464
)
  
21,593
  
   
$
39,410
      
$
(12,457
)
$
26,953
  
 
Scheduled amortization of these debt issuance costs related to the Senior Notes for the next five years is estimated to be $23.4 million.
 
NOTE 8—FINANCIAL INSTRUMENTS
 
Derivative Instruments

On our behalf, Cheniere Marketing has entered into financial derivatives to hedge the exposure to variability in expected future cash flows attributable to the future sale of natural gas from our LNG commissioning cargoes (“LNG commissioning cargo derivatives”). Prior to September 30, 2009, the net cost (LNG commissioning cargo purchase price less natural gas sales proceeds) of our LNG commissioning cargoes was capitalized on our Consolidated Balance Sheets as it was directly related to the LNG receiving terminal construction and was incurred to place the LNG receiving terminal in usable condition. However, changes in the fair value of our LNG commissioning cargo derivatives are reported in earnings because they do not meet the criteria to be designated as a hedging instrument that is required to qualify for cash flow hedge accounting.

Effective January 1, 2008, we adopted accounting standards that established a framework for measuring fair value, expanded disclosures about fair value measurements and permitted entities to choose to measure many financial instruments and certain other items at fair value.  We elected not to measure any additional financial assets or liabilities at fair value, other than those which were recorded at fair value prior to adoption.

The estimated fair value of financial instruments is the amount at which the instrument could be exchanged currently between willing parties. The fair value of our commodity futures contracts are based on inputs that are quoted prices in active markets for identical assets or liabilities, resulting in Level 1 categorization of such measurements. The following table (in thousands) sets forth, by level within the fair value hierarchy, the fair value of our financial assets and liabilities at December 31, 2009:
 
 
Quoted Prices in Active Markets for Identical Instruments
(Level 1)
  
Significant Other Observable Inputs (Level 2)
  
Significant Other Observable Inputs (Level 3)
  
Total Carrying Value at  December 31, 2009
  
Derivatives asset
$
124   
 
$
—  
 
$
—  
 
$
124   
 

Derivatives asset reflect LNG commissioning cargo derivative positions held by Cheniere Marketing on behalf of Sabine Pass LNG related to natural gas swaps entered into to mitigate the price risk from sales of excess LNG purchased for commissioning and performance testing.

 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 

Other Financial Instruments

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

Financial Instruments (in thousands):
 
   
December 31, 2009
    
December 31, 2008
  
   
Carrying
Amount
    
Estimated
Fair Value
    
Carrying
Amount
    
Estimated
Fair Value
  
2013 Notes (1)
   $ 550,000     $ 503,250     $ 550,000     $ 412,500  
2016 Notes, net of discount (1)
     1,633,029       1,371,744       1,628,334       1,204,967  
Note to affiliate (2)
     —         —         2,372       2,379  
Restricted U.S. Treasury securities (3)
     —         —         20,829       22,901  
 
(1)
The fair value of the Senior Notes was based on quotations obtained from broker-dealers who made markets in these and similar instruments as of December 31, 2009 and December 31, 2008.
(2)
The note to affiliate bears interest at a fixed 7½% rate. Management estimates that the carrying amount is a reasonable approximation of the fair value as of December 31, 2009 and 2008.
(3)
The fair value of our restricted U.S. Treasury securities was based on quotations obtained from broker-dealers who made markets in these and similar instruments as of December 31, 2009 and 2008.

NOTE 9—ACCRUED LIABILITIES
 
As of December 31, 2009 and 2008, accrued liabilities consisted of the following (in thousands):

   
December 31,
  
   
2009
    
2008
  
Interest and related debt fees
   $ 14,152     $ 14,152  
LNG terminal construction costs
     7,850       26,617  
Affiliate
     3,095       184  
Other
     179       157  
Accrued liabilities
   $ 25,276     $ 41,110  
 
NOTE 10—DEFERRED REVENUE
 
In November 2004, Total Gas and Power North America, Inc. (formerly known as Total LNG USA, Inc.) (“Total”) paid Sabine Pass LNG a nonrefundable advance capacity reservation fee of $10.0 million in connection with the reservation of approximately 1.0 Bcf/d of LNG regasification capacity at the Sabine Pass LNG receiving terminal. An additional advance capacity reservation fee payment of $10.0 million was paid by Total to Sabine Pass LNG in April 2005. The advance capacity reservation fee payments are being amortized as a reduction of Total’s regasification capacity reservation fee under its TUA over a 10-year period beginning with the commencement of its TUA on April 1, 2009. As a result, we recorded the advance capacity reservation fee payments that Sabine Pass LNG received, although non-refundable, as deferred revenue to be amortized to income over the corresponding 10-year period.

In November 2004, Sabine Pass LNG also entered into a TUA to provide Chevron U.S.A., Inc. (“Chevron”) with approximately 0.7 Bcf/d of LNG regasification capacity at the Sabine Pass LNG receiving terminal. In December 2005, Chevron exercised its option to increase its reserved capacity by approximately 0.3 Bcf/d to approximately 1.0 Bcf/d, making advance capacity reservation fee payments to Sabine Pass LNG totaling $20.0 million. The advance capacity reservation fee payments are being amortized as a reduction of Chevron’s regasification capacity reservation fee under its TUA over a 10-year period beginning with the commencement of its TUA on July 1, 2009. As a result, we recorded the advance capacity reservation fee payments that Sabine Pass LNG received, although non-refundable, as deferred revenue to be amortized to income over the corresponding 10-year period.

As of December 31, 2009 and 2008, we had recorded $26.5 million and $2.5 million as current deferred revenue, respectively, and $33.5 million and $37.5 million as non-current deferred revenue related to Total and Chevron advance capacity reservation fee payments.
 
Following the achievement of commercial operability of the Sabine Pass LNG receiving terminal in September 2008, Sabine

 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 

Pass LNG began receiving capacity reservation fee payments from Cheniere Marketing under its TUA. As of December 31, 2009 and 2008, we had recorded $63.5 million and $62.7 million as current deferred revenue, respectively, primarily related to Cheniere Marketing’s advance capacity reservation fee payments.

In July 2007, Sabine Pass LNG executed Cooperative Endeavor Agreements (“CEAs”) with various Cameron Parish, Louisiana taxing authorities that allow them to accelerate certain of its property tax payments scheduled to begin in 2019. This ten-year initiative represents an aggregate $25.0 million commitment, and will make resources available to the Cameron Parish taxing authorities on an accelerated basis in order to aid in their reconstruction efforts following Hurricane Rita. In exchange for Sabine Pass LNG’s advance payments of ad valorem taxes, Cameron Parish will grant Sabine Pass LNG a dollar for dollar credit against future ad valorem taxes to be levied against its LNG receiving terminal starting in 2019. In September 2007, Sabine Pass LNG entered into an agreement with Cheniere Marketing, pursuant to which Cheniere Marketing will advance it any and all amounts payable under the CEAs in exchange for a similar amount of credits against future ad valorem reimbursements it would owe to Sabine Pass LNG under its TUA starting in 2019. These advance ad valorem tax payments were recorded to other assets, and payments from Cheniere Marketing that Sabine Pass LNG utilized to make the early payment of taxes were recorded as deferred revenue. As of December 31, 2009 and 2008, we had $7.4 million and $5.0 million, respectively, of other assets and deferred revenue resulting from accelerated ad valorem tax payments.
 
NOTE 11—LONG-TERM DEBT (including related party)
 
As of December 31, 2009 and 2008, our long-term debt consisted of the following (in thousands):

   
December 31,
  
   
2009
    
2008
  
Senior Notes, net of discount
   $ 2,110,101     $ 2,107,673  
Senior Notes—related party, net of discount
     72,928       70,661  
Long-term note—affiliate
     —         2,372  
Total long-term debt
   $ 2,183,029     $ 2,180,706  
 
Senior Notes
 
In November 2006, Sabine Pass LNG issued an aggregate principal amount of $2,032.0 million of Senior Notes, consisting of $550.0 million of the 2013 Notes and $1,482.0 million of the 2016 Notes. In September 2008, Sabine Pass LNG issued an additional $183.5 million, before discount, of 2016 Notes whose terms were identical to the previously outstanding 2016 Notes. The net proceeds received from the additional issuance of 2016 Notes were $145.0 million.  The additional issuance and the previously outstanding 2016 Notes are treated as a single series of notes under the Sabine Pass Indenture. Sabine Pass LNG placed $100.0 million of the $145.0 million of net proceeds from the additional issuance of the 2016 Notes into a construction account to pay construction expenses of cost overruns related to the construction, cool down, commissioning and completion of the Sabine Pass LNG receiving terminal. In addition, Sabine Pass LNG placed $40.8 million of the remaining net proceeds into an account in accordance with the cash waterfall requirements of the security deposit agreement Sabine Pass LNG entered into in connection with the Senior Notes, which are used by Sabine Pass LNG for working capital and other general business purposes.
 
Interest on the Senior Notes is payable semi-annually in arrears on May 30 and November 30 of each year. The Senior Notes are secured on a first-priority basis by a security interest in all of Sabine Pass LNG’s equity interests and substantially all of its operating assets. Under the Sabine Pass Indenture, except for permitted tax distributions, Sabine Pass LNG may not make distributions until certain conditions are satisfied: there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment of approximately $82.4 million. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the Sabine Pass Indenture. During the years ended December 31, 2009 and 2008, Sabine Pass LNG made distributions of $295.7 million and zero, respectively, to us after satisfying all the applicable conditions in the Sabine Pass Indenture.
 
Long-Term Note—Affiliate
 
In March 2007, we entered into a $12.0 million unsecured revolving credit note with Cheniere LNG Financial Services, Inc., a wholly-owned subsidiary of Cheniere, to be paid upon demand but no sooner than January 1, 2010, or the date on which we have sufficient available cash. The purpose of this note was to provide funds for the payment of certain public company and other expenses that could not be funded by the Senior Notes. Interest on borrowings under this note was at a fixed rate of 7½% with unpaid interest compounded semi-annually. In January 2009, we repaid the $2.5 million outstanding balance on our $12.0 million unsecured revolving credit note.
 
 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
NOTE 12—DESCRIPTION OF EQUITY INTERESTS
 
The common units and subordinated units represent limited partner interests in us. The holders of the units are entitled to participate in partnership distributions and exercise the rights and privileges available to limited partners under our partnership agreement. On May 31, 2007, Cheniere LNG Holdings, LLC (“Holdings”) contributed all of its 135,383,831 subordinated units to Cheniere Subsidiary Holdings, LLC.
 
The common units and general partner units have the right to receive minimum quarterly distributions of $0.425 and $0.069 per unit, respectively, plus any arrearages thereon, before any distribution is made to the holders of the subordinated units. Subordinated units will convert into common units on a one-for-one basis when the subordination period ends. The subordination period will end when we meet financial tests specified in the partnership agreement.
 
The general partner interest is entitled to at least 2% of all distributions made by us. In addition, the general partner holds incentive distribution rights, which allow the general partner to receive a higher percentage of quarterly distributions of available cash from operating surplus after the minimum distributions have been achieved and as additional target levels are met. The higher percentages range from 15% up to 50%.
 
NOTE 13—RELATED PARTY TRANSACTIONS
 
As of December 31, 2009 and 2008, we had $5.4 million and $2.2 million of advances to affiliates, respectively.  In addition, we have entered into the following related party transactions:

 TUA Agreement
 
Cheniere Marketing has reserved approximately 2.0 Bcf/d of regasification capacity under a firm commitment TUA and is required to make capacity reservation fee payments aggregating approximately $250 million per year for the period from January 1, 2009, through at least September 30, 2028. Cheniere has guaranteed Cheniere Marketing’s obligations under its TUA.
 
LNG Lease Agreement
 
In September 2008, Sabine Pass LNG entered into an agreement in the form of a lease with Cheniere Marketing that enabled Sabine Pass LNG to hedge the exposure to variability in expected future cash flows of its commissioning cargoes. The agreement permitted Cheniere Marketing to deliver LNG to the Sabine Pass LNG receiving terminal and to receive regasified LNG for redelivery as natural gas in exchange for the use of the properties of the LNG to cool down the Sabine Pass LNG receiving terminal. Under the terms of the agreement, Sabine Pass LNG paid Cheniere Marketing a fixed fee based on the delivered quantity of LNG in each LNG cargo. Sabine Pass LNG assumed full price risk of the purchase and sale of the LNG and also financed all activities relating to the LNG. Cheniere Marketing held title to the LNG at all times and sold all redelivered LNG and remitted the net proceeds from such sales back to Sabine Pass LNG.
 
    LNG purchased on behalf of Sabine Pass LNG by Cheniere Marketing that was funded by Sabine Pass LNG was recorded at historical cost and classified as a non-current asset on our Consolidated Balance Sheets as Advances to Affiliate—LNG Held for Commissioning. LNG that was lost, used as fuel or sold resulted in the reduction of Advances to Affiliate—LNG Held for Commissioning on our Consolidated Balance Sheets at historical cost. During the second quarter of 2008 and the first quarter of 2009, Sabine Pass LNG advanced Cheniere Marketing funds to purchase LNG. As of September 30, 2009, commissioning activities and construction of the Sabine Pass LNG receiving terminal were substantially complete; therefore we no longer needed the remaining LNG for commissioning. We had 1,115,000 MMBtu of LNG Held for Commissioning remaining at September 30, 2009 which was reclassified to current assets as $3.5 million of Advances to Affiliate—LNG inventory, representing the market value of LNG inventory that we have retained for operations. LNG inventory is recorded at cost and is subject to lower of cost or market adjustments at the end of each period.  Inventory cost is determined using the average cost method. Recoveries of losses resulting from interim period LCM adjustments are made due to market price recoveries on the same inventory in the same fiscal year and are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. At December 31, 2009, we had $1.3 million Advances to Affiliate—LNG inventory and zero Advances to Affiliate—LNG Held for Commissioning on our Consolidated Balance Sheets. At December 31, 2008, we had $9.9 million recorded as Advances to Affiliate—LNG Held for Commissioning on our Consolidated Balance Sheets.
 
 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
During the years ended December 31, 2009 and 2008, Sabine Pass LNG incurred fixed fees from Cheniere Marketing of $0.3 million and $0.6 million, respectively, which we capitalized as property, plant and equipment on our Consolidated Balance Sheets.
 
Service Agreements
 
In February 2005, Sabine Pass LNG entered into a 20-year operation and maintenance agreement with a wholly-owned subsidiary of Cheniere pursuant to which we receive all necessary services required to construct, operate and maintain the Sabine Pass LNG receiving terminal. Prior to substantial completion of the Sabine Pass LNG receiving terminal, as defined in Sabine Pass LNG’s engineering, procurement and construction (“EPC”) contract with Bechtel Corporation (“Bechtel”), Sabine Pass LNG was required to pay a fixed monthly fee of $95,000 (indexed for inflation) under the agreement. The fixed monthly fee increased to $130,000 (indexed for inflation) upon the achievement of substantial completion of the Sabine Pass LNG receiving terminal in March 2009, and the counterparty is entitled to a bonus equal to 50% of the salary component of labor costs in certain circumstances to be agreed upon between Sabine Pass LNG and the counterparty at the beginning of each operating year. In addition, Sabine Pass LNG is required to reimburse the counterparty for its operating expenses, which consist primarily of labor expenses.
 
In February 2005, Sabine Pass LNG entered into a 20-year management services agreement with its general partner, which is a wholly-owned subsidiary of us, pursuant to which its general partner was appointed to manage the construction and operation of the Sabine Pass LNG receiving terminal, excluding those matters provided for under the operation and maintenance agreement described in the paragraph above. In August 2008, the general partner of Sabine Pass LNG assigned all of its rights and obligations under the management services agreement to Cheniere LNG Terminals, Inc. (“Cheniere Terminals”), a wholly-owned subsidiary of Cheniere. Prior to substantial completion of the Sabine Pass LNG receiving terminal, as defined in Sabine Pass LNG’s EPC contract with Bechtel, Sabine Pass LNG was required to pay Cheniere Terminals a monthly fixed fee of $340,000 (indexed for inflation). With the achievement of substantial completion of the Sabine Pass LNG receiving terminal in March 2009, the monthly fixed fee increased to $520,000 (indexed for inflation).
 
In March 2007, we entered into a services agreement with Cheniere Terminals pursuant to which we pay Cheniere Terminals an annual administrative fee of $10.0 million (adjusted for inflation) for the provision of various general and administrative services for our benefit following the closing of our initial public offering. Payments under this services agreement commenced January 1, 2009. In addition, we reimburse Cheniere Terminals for its services in an amount equal to the sum of all out-of-pocket costs and expenses incurred by Cheniere Terminals that are directly related to our business or activities.
 
During the years ended December 31, 2009, 2008 and 2007, we paid an aggregate of $18.5 million, $5.2 million and $5.2 million, respectively, under the foregoing service agreements from restricted cash and cash equivalents.
 
Agreement to Fund Sabine Pass LNG’s Cooperative Endeavor Agreements (“CEAs”)
 
In July 2007, Sabine Pass LNG executed Cooperative Endeavor Agreements (“CEAs”) with various Cameron Parish, Louisiana taxing authorities that allow them to collect certain annual property tax payments from Sabine Pass LNG in 2007 through 2016. This ten-year initiative represents an aggregate $25.0 million commitment and will make resources available to the Cameron Parish taxing authorities on an accelerated basis in order to aid in their reconstruction efforts following Hurricane Rita. In exchange for Sabine Pass LNG’s payments of annual ad valorem taxes, Cameron Parish will grant Sabine Pass LNG a dollar for dollar credit against future ad valorem taxes to be levied against the Sabine Pass LNG receiving terminal starting in 2019. In September 2007, Sabine Pass LNG modified its TUA with Cheniere Marketing, pursuant to which Cheniere Marketing will pay Sabine Pass LNG additional TUA revenues equal to any and all amounts payable under the CEAs in exchange for a similar amount of credits against future TUA payments it would owe Sabine Pass LNG under its TUA starting in 2019. These TUA payments were recorded to other assets, and payments from Cheniere Marketing that Sabine Pass LNG utilized to make the ad valorem tax payments were recorded as deferred revenue. As of December 31, 2009 and 2008, we had $7.4 million and $5.0 million of other assets and deferred revenue resulting from Sabine Pass LNG’s ad valorem tax payments and the advance TUA payments received from Cheniere Marketing, respectively.
 
Contracts for Sale and Purchase of Natural Gas
 
In 2007, we entered into a number of related party agreements for the purchase and sale of natural gas with Cheniere Marketing. During the years ended December 31, 2009 and 2008, Sabine Pass LNG did not sell or purchase any natural gas under its purchase and sale agreements with Cheniere Marketing.
 
 
58
 
CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
Contract for Commissioning Activities
 
Sabine Pass LNG has entered into a number of related party agreements for commissioning activities with Cheniere Marketing. During the years ended December 31, 2009 and 2008, Sabine Pass LNG paid an aggregate of zero and $34.6 million, respectively, under these commissioning activities agreements with Cheniere Marketing.
 
NOTE 14—LEASES

The following is a schedule by years of future minimum rental payments, excluding inflationary adjustments, required as of December 31, 2009 under the land leases and tug boat lease described below (in thousands):

Year ending December 31:
  
Lease Payments (2)
  
2010
$
8,905
  
2011
  
8,905
  
2012
  
8,905
  
2013
  
8,905
  
2014
  
8,905
  
Later years (1)
  
230,009
  
Total minimum payments required
$
274,534
  
  
(1)  
The later years include the remaining initial term and six 10-year extensions of Sabine Pass LNG’s land leases and the remaining initial term and two 5-year extensions of Sabine Pass LNG’s tug boat lease, as the lease option renewals were reasonably assured.
 
(2)  
Lease payments for Sabine Pass LNG’s tug boat lease represent its lease payment obligation and do not take into account the $129.6 million of sublease payments Sabine Pass LNG will receive from its three TUA customers that effectively offset this lease payment obligation, as discussed below.

Land Leases

In January 2005, Sabine Pass LNG exercised its options and entered into three land leases for the site of the Sabine Pass LNG receiving terminal.  The leases have an initial term of 30 years, with options to renew for six 10-year extensions with similar terms as the initial term. In February 2005, two of the three leases were amended, increasing the total acreage under lease to 853 acres and increasing the annual lease payments to $1.5 million.  The annual lease payment is adjusted for inflation every five years based on a consumer price index, as defined in the lease agreements.

Tug Boat Lease

As described in Note 1—“Nature of Operations,” in the second quarter of 2009 Sabine Pass LNG acquired a lease for the use of tug boats and marine services at the Sabine Pass LNG receiving terminal as a result of its purchase of Tug Services.  The term of the Tug Agreement commenced in January 2008 for a period of 10 years, with an option to renew two additional, consecutive terms of five years each.  We have determined that the Tug Agreement contains a lease for the tugs specified in the Tug Agreement.  In addition, we have concluded that the tug lease contained in the Tug Agreement is an operating lease, and as such, the equipment component of the Tug Agreement will be charged to expense over the term of the Tug Agreement as it becomes payable.

In connection with this acquisition, Tug Services entered into a Tug Sharing Agreement with our three TUA customers to provide their LNG cargo vessels with tug boat and marine services at our LNG receiving terminal and effectively offset the cost of our lease. The Tug Sharing Agreement provides for each of our customers to pay Tug Services an annual service fee.

 
 
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CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 
 
NOTE 15—COMMITMENTS AND CONTINGENCIES
 
Construction Agreements
 
In July 2006, Sabine Pass LNG entered into various construction agreements to expand the Sabine Pass LNG receiving terminal to approximately 4.0 Bcf/d with storage capacity of approximately 16.9 Bcf, some of which include the following:
 
Sabine Pass LNG entered into an engineering, procurement, construction and management (“EPCM”) agreement with Bechtel Corporation (“Bechtel”) pursuant to which Bechtel provided design and engineering services for the Sabine Pass LNG receiving terminal expansion project, except for such portions to be designed by other contractors and suppliers of equipment, materials and services 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 initial terms of the EPCM agreement, Bechtel was paid on a cost reimbursable basis, plus a fixed fee in the initial amount of $18.5 million. A discretionary bonus was paid to Bechtel at Sabine Pass LNG’s sole discretion upon completion. As of December 31, 2009, Sabine Pass LNG was committed to make cash payments of approximately $2.6 million in the future pursuant to this contract.
 
Sabine Pass LNG entered into an EPC LNG tank contract with Zachry Construction Corporation (“Zachry”) and Diamond LNG LLC (“Diamond”), pursuant to which Zachry and Diamond furnished all plant, labor, materials, tools, supplies, equipment, transportation, supervision, technical, professional and other services, and performed all operations necessary and required to satisfactorily engineer, procure materials for and construct two additional storage tanks. The EPC LNG tank contract provided that Zachry and Diamond would receive a lump-sum, total fixed price payment for the two storage tanks of approximately $140.9 million, which was subject to adjustment based on fluctuations in the cost of labor and certain materials, including the steel used in the additional storage tanks, and change orders. As of December 31, 2009, Sabine Pass LNG was committed to make cash payments of approximately $3.6 million in the future pursuant to this contract.
 
LNG Commitments
 
Sabine Pass LNG has entered into TUAs with Total, Chevron and Cheniere Marketing to provide berthing for LNG vessels and for the unloading, storage and regasification of LNG at the Sabine Pass LNG receiving terminal.
 
Services Agreements
 
We have entered into certain services agreements with affiliates. See Note 13—“Related Party Transactions” for information regarding such agreements.
 
Public Company Expenses
 
We and Sabine Pass LNG are reporting entities under the Exchange Act. As a result, our combined total annual general and administrative expenses will include costs related to compliance with the Sarbanes-Oxley Act of 2002, filing annual and quarterly reports with the SEC, increased audit fees, tax compliance and publicly traded partnership tax reporting, investor relations, director compensation, directors’ and officers’ insurance, legal fees, registrar and transfer agent fees and stock exchange fees. Cheniere has advanced us funds to pay public company expenses associated with being a publicly traded partnership through 2008, after which time we will use available cash to pay such expenses directly and, after payment of the initial quarterly distribution on all units, to reimburse Cheniere.
 
Crest Royalty
 
Under a settlement agreement dated as of June 14, 2001, Cheniere agreed to pay a royalty, which we refer to as the Crest Royalty. This Crest Royalty is calculated based on the volume of natural gas processed through covered LNG facilities. The Freeport LNG Development, L.P. (“Freeport LNG”) and Sabine Pass LNG receiving terminals are covered facilities. Freeport LNG has assumed the obligation to pay the Crest Royalty for natural gas processed at Freeport LNG’s receiving terminal. Cheniere has agreed to indemnify us against any Crest Royalty obligation and to pay any Crest Royalty amounts that may be due and not paid by Freeport LNG. The Crest Royalty is subject to a maximum of approximately $11.0 million per production year at throughput of approximately 1.0 Bcf/d and a minimum of $2.0 million.  The first production year began in April 2009.

 
60
 
CHENIERE ENERGY PARTNERS, L.P. AND SUBSIDIARIES
 
NOTES TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS—CONTINUED
 

Restricted Net Assets
 
At December 31, 2009, our restricted net assets of consolidated subsidiaries were approximately ($481) million.

Other Commitments
 
State Tax Sharing Agreement
 
In November 2006, Sabine Pass LNG entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all Texas franchise tax returns which it and Sabine Pass LNG are required to file on a combined basis and to timely pay the combined Texas franchise tax liability. If Cheniere, in its sole discretion, demands payment, Sabine Pass LNG will pay to Cheniere an amount equal to the Texas franchise tax that Sabine Pass LNG would be required to pay if its Texas franchise tax liability were computed on a separate company basis. This agreement contains similar provisions for other state and local taxes that Cheniere and Sabine Pass LNG are required to file on a combined, consolidated or unitary basis. The agreement is effective for tax returns first due on or after January 1, 2008. As of December 31, 2009, we had made no payments to Cheniere under this agreement.
 
Cooperative Endeavor Agreements
 
See description of CEAs in Note 13—“Related Party Transactions.”
 
Legal Proceedings
 
We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. In the opinion of management, as of December 31, 2009, there were no threatened or pending legal matters that would have a material impact on our consolidated results of operations, financial position or cash flows.
 
NOTE 16—SUPPLEMENTAL CASH FLOW INFORMATION AND DISCLOSURES OF NON-CASH TRANSACTIONS
 
The following table provides supplemental disclosure of cash flow information (in thousands):

 
Year Ended December 31,
  
 
2009
  
2008
  
2007
  
Cash paid for interest, net of amounts capitalized
   $ 138,659     $ 77,243     $ 93,642  
Non-cash equity contribution
     —         —         —    
Construction-in-process and debt issuance additions funded with accrued liabilities
     (66 )     9,893       60,555  
 

 
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SUPPLEMENTAL INFORMATION TO CONSOLIDATED COMBINED FINANCIAL STATEMENTS
SUMMARIZED QUARTERLY FINANCIAL DATA
(unaudited)
 
Quarterly Financial Data—(in thousands, except per unit amounts)

   
First
Quarter
    
Second
Quarter
    
Third
Quarter
    
Fourth
Quarter
  
Year ended December 31, 2009:
                        
Revenues
   $ 62,549     $ 95,695     $ 128,533     $ 130,013  
Income from operations
     43,396       74,282       106,367       103,875  
Net income
     13,588       41,951       69,501       61,872  
Net income per limited partner unit
   $ 0.08     $ 0.26     $ 0.43     $ 0.37  
                                 
Year ended December 31, 2008:
                                
Revenues
   $ —       $ —       $ —       $ 15,000  
Loss from operations
     (4,100 )     (2,748 )     (10,026 )     (267 )
Net loss
     (14,515 )     (24,513 )     (10,897 )     (28,419 )
Net loss per limited partner unit
   $ (0.09 )   $ (0.15 )   $ (0.07 )   $ (0.17 )
 
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
 
None.
 
ITEM 9A. CONTROLS AND PROCEDURES
 
Evaluation of Disclosure Controls and Procedures
 
Based on their evaluation as of the end of the fiscal year ended December 31, 2009, our general partner’s principal executive officer and principal financial officer have concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) are effective to ensure that information required to be disclosed in reports that we file or submit under the Exchange Act are (i) accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and (ii) recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.
 
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.
 
Management Report on Internal Control Over Financial Reporting
 
Our Management Report on Internal Control Over Financial Reporting is included in the Consolidated Combined Financial Statements on page 41 and is incorporated herein by reference.
 
ITEM 9B. OTHER INFORMATION
 
None.

 
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PART III
 
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS OF OUR GENERAL PARTNER AND CORPORATE GOVERNANCE
 
Management of Cheniere Energy Partners, L.P.
 
Cheniere Energy Partners GP, LLC (“Cheniere GP”), as our general partner, manages our operations and activities. Our general partner is not elected by our unitholders and is not subject to re-election on a regular basis in the future. The directors of our general partner are elected by the sole member of the general partner.  Unitholders are not entitled to elect the directors of our general partner or to participate directly or indirectly in our management or operations.
 
Audit Committee
 
The board of directors of our general partner has appointed an audit committee composed of Mike Bock, Lon McCain and Robert Sutcliffe, each of whom is an independent director and satisfies the additional independence and other requirements for audit committee members provided for in the listing standards of the NYSE Amex and the Exchange Act. In addition, the board of directors of our general partner has determined that Mike Bock and Lon McCain meet the qualifications of a “financial expert” and are “financially sophisticated” as such terms are defined by the SEC and the NYSE Amex, respectively.
 
The audit committee assists the board of directors of our general partner in its oversight of the integrity of our financial statements and our compliance with legal and regulatory requirements and partnership policies and controls. The audit committee has the sole authority to retain and terminate our independent registered public accounting firm, approve all audit services and related fees and the terms thereof, and pre-approve any non-audit services to be rendered by our independent registered public accounting firm. The audit committee is also responsible for confirming the independence and objectivity of our independent registered public accounting firm. Our independent registered public accounting firm has been given unrestricted access to the audit committee.
 
Conflicts Committee
 
Under our partnership agreement, the board of directors of our general partner has appointed a conflicts committee composed of the independent directors, Mike Bock, Lon McCain and Robert Sutcliffe, to review specific matters that the board believes may involve conflicts of interest. The conflicts committee will determine if the resolution of a conflict of interest is fair and reasonable to us. The members of the conflicts committee may not be security holders, officers or employees of our general partner, directors, officers, or employees of affiliates of the general partner or holders of any ownership interest in us other than common units or other publicly traded units and must meet the independence standards established by the NYSE Amex, the Exchange Act and other federal securities laws. Any matter approved by the conflicts committee is conclusively deemed to be fair and reasonable to us, approved by all of our partners and not a breach by our general partner of any duties that it may owe us or our unitholders.
 
Other
 
We do not have a nominating committee because the directors of our general partner manage our operations. The directors of our general partner are not elected by our unitholders and are not subject to re-election on a regular basis. Unitholders are not entitled to elect the directors of our general partner or to participate directly or indirectly in our management or operations.
 
We also do not have a compensation committee. We have no employees, directors or officers. We are managed by our general partner, Cheniere GP. Our general partner has paid no cash compensation to its executive officers since its inception. All of the executive officers of our general partner are also executive officers of Cheniere. Cheniere compensates these officers for the performance of their duties as executive officers of Cheniere, which includes managing our partnership. Cheniere does not allocate this compensation between services for us and services for Cheniere and its affiliates.
 
 
63
 

Directors and Executive Officers of Our General Partner
 
We have no employees, directors or officers. We are managed by our general partner, Cheniere GP. The following sets forth information, as of February 15, 2010, regarding the individuals who currently serve on the board of directors and as executive officers of our general partner. Charif Souki, Don Turkleson and Walter Williams have served as directors of the general partner since 2006. Meg Gentle, Lon McCain and Robert Sutcliffe have served as directors of the general partner since 2007. Keith Teague and James Bennett have served as directors of the general partner since 2008.  Mike Bock was elected as a director of the general partner in 2009.
 
     
Name
Age
    Position with Our General Partner
Charif Souki
57
Director, Chairman of the Board and Chief Executive Officer
R. Keith Teague
45
Director, President and Chief Operating Officer
Meg A. Gentle
35
Director, Senior Vice President and Chief Financial Officer
James D. Bennett
40
Director
Michael E.  Bock
44
Director
Lon McCain
62
Director
Robert J. Sutcliffe
58
Director
Don A. Turkleson
55
Director
Walter L. Williams
82
Director
 
Charif Souki is Chairman of the Board of Directors and Chief Executive Officer of our general partner and has held that officer position since January 2007. Mr. Souki, a co-founder of Cheniere, is Chairman of Cheniere’s board of directors and Chief Executive Officer and President of Cheniere. Since December 2002, Mr. Souki has been the Chief Executive Officer of Cheniere, and he was also President of Cheniere from that time until April 2005. He was re-elected as President in April 2008. From June 1999 to December 2002, he was Chairman of the board of directors of Cheniere and an independent investment banker. From September 1997 until June 1999, he was co-chairman of the board of directors of Cheniere, and he served as Secretary of Cheniere from July 1996 until September 1997. Mr. Souki has over 20 years of independent investment banking experience in the oil and gas industry and has specialized in providing financing for small capitalization companies with an emphasis on the oil and gas industry. Mr. Souki received a B.A. from Colgate University and an M.B.A. from Columbia University. Mr. Souki is also a director and Chief Executive Officer of the general partner of Sabine Pass LNG, L.P. It was determined that Mr. Souki should serve as a director of our general partner because he is the Chief Executive Officer of Cheniere, Cheniere GP and the general partner of Sabine Pass LNG, L.P. and is responsible for developing the companies’ overall strategy and vision and implementing the business plans.  In addition, with twenty years of experience as an investment banker specializing in the oil and gas industry, Mr. Souki brings a unique perspective to the board of directors of the general partner.  Mr. Souki has not held any other directorship positions in the past five years.
 
R. Keith Teague is a director and President and Chief Operating Officer of our general partner and has held those officer positions since June 2008. He has served as Senior Vice President—Asset Group of Cheniere since April 2008. Prior to that time, he served as Vice President—Pipeline Operations of Cheniere beginning in May 2006. He has also served as President of Cheniere Pipeline Company, a wholly-owned subsidiary of Cheniere, since January 2005. Mr. Teague began his career with Cheniere in February 2004 as Director of Facility Planning. Prior to joining Cheniere, Mr. Teague served as the Director of Strategic Planning for the CMS Panhandle Companies from December 2001 until September 2003. Mr. Teague is also President of the general partner of Sabine Pass LNG, L.P. and is responsible for the development, construction and operation of Cheniere’s LNG receiving terminal and pipeline assets.  With Mr. Teague’s  knowledge and expertise relating to the Sabine Pass LNG receiving terminal, it was determined that he should serve as a director of our general partner. Mr. Teague received a B.S. in civil engineering from Louisiana Tech University and an M.B.A. from Louisiana State University. Mr. Teague has not held any other directorship positions in the past five years.
 
 Meg A. Gentle is a director and Senior Vice President and Chief Financial Officer of our general partner and has held that officer position since March 2009. She served as Senior Vice President of our general partner from June 2008 to March 2009.  She has served as Senior Vice President and Chief Financial Officer of Cheniere since March 2009. She served as Senior Vice President – Strategic Planning and Finance from February 2008 to March 2009.  Prior to that time, she served as Vice President of Strategic Planning since September 2005 and Manager of Strategic Planning since June 2004.  Prior to joining Cheniere, Ms. Gentle spent eight years in energy market development, economic evaluation and long-range planning. She conducted international business development and strategic planning for Anadarko Petroleum Corporation, an oil and gas exploration and production company, for six years and energy market analysis for Pace Global Energy Services, an energy management and consulting firm, for two years. Ms. Gentle received her B.A. in economics and international affairs from James Madison University and an M.B.A. from Rice University.  Ms. Gentle is also Chief Financial Officer of the general partner of Sabine Pass LNG, L.P.  It was determined that Ms. Gentle should serve as a director of our general partner because of her experience with strategic planning and finance in the energy industry and because of the perspective she brings as the Chief Financial Officer of Cheniere, Cheniere GP and the general partner of Sabine Pass LNG, L.P.  Ms. Gentle has not held any other directorship positions in the past five years.

 
64
 

James D. Bennett is a director of our general partner. Mr. Bennett is a Managing Director with GSO Capital Partners LP (“GSO”) and has been involved in many of GSO’s private equity and mezzanine investments in the energy industry. Prior to joining GSO Capital Partners in 2005, Mr. Bennett served as Chief Financial Officer of Aquilex Service Corporation, which provides specialty repair services to refining and power generation facilities worldwide. Prior to that time, Mr. Bennett was vice president of operations at Exario Networks, a provider of telecommunications solutions, from 2000 to 2001. Before that time, Mr. Bennett was in the investment banking group of Donaldson, Lufkin & Jenrette where he was involved in transactions for companies in all segments of the energy industry from 1995 to 2000. Mr. Bennett started his career in corporate banking at NationsBank in 1993. Mr. Bennett received a B.B.A. in Finance from Texas Tech University and currently serves as a director of United Engines, LLC, an oil field equipment manufacturer and repair services provider, and Crestwood Midstream Partners, LLC, a midstream energy company.  Mr. Bennett was nominated by GSO to serve on the board of directors of our general partners pursuant to the Investors’ Agreement, dated August 15, 2008, among Cheniere, Cheniere Common Units Holding, LLC, GSO and the other investors named therein.  Under the terms and conditions of the Investors’ Agreement, the investors have the right to cause the election of one nominee to the board of directors of Cheniere GP.  In addition, Mr. Bennett brings an investor’s perspective to board decisions.

Michael E. Bock is a director of our general partner.  He also is a member of the Audit Committee and the Conflicts Committee.  Mr. Bock was a Managing Director in the Global Energy and Power Group at Merrill Lynch from December 2006 to April 2009.  Prior to that time, he was a Principal and head of Corporate Finance at Petrie Parkman & Co., an investment banking specializing in the energy industry.  Mr. Bock earned a bachelor of arts from Harvard University in 1987.  He is also a Chartered Financial Analyst and a member of CFA Institute and the CFA Society of Colorado.  It was determined that Mr. Bock should serve as a director of our general partner because of his fifteen years of experience as an investment banker in the energy industry as well as his expertise as a Chartered Financial Analyst.  Mr. Bock has not held any other directorship positions in the past five years. 
 
Lon McCain is a director of our general partner and serves as the Chairman of the Audit Committee and a member of the Conflicts Committee. He is Executive Vice President and Chief Financial Officer of Ellora Energy Inc., a private, independent exploration and production company.  Prior to that, he was Vice President, Treasurer and Chief Financial Officer of Westport Resources Corporation, a publicly traded exploration and production company, from 2001 until the sale of that company to Kerr-McGee Corporation in 2004. From 1992 until joining Westport, Mr. McCain was Senior Vice President and Principal of Petrie Parkman & Co., an investment banking firm specializing in the oil and gas industry. From 1978 until joining Petrie Parkman, Mr. McCain held senior financial management positions with Presidio Oil Company, Petro-Lewis Corporation and Ceres Capital. He is currently on the board of directors of Transzap, Inc., a provider of digital data and electronic payment solutions, Crimson Exploration, Inc., a publicly traded oil and natural gas exploration and production company, and Continental Resources, Inc., a publicly traded oil and natural gas exploration and production company.  He previously served on the board of directors of GulfWest Energy, Inc. until it merged with Crimson Exploration, Inc., its wholly-owned subsidiary, in June 2005.  Mr. McCain received a B.S. in business administration and a Masters of Business Administration/Finance from the University of Denver. Mr. McCain was also an Adjunct Professor of Finance at the University of Denver from 1982 to 2005.  It was determined that Mr. McCain should serve as a director of our general partners because of his experience as a chief financial officer for energy companies and his background as an investment banker in the energy industry.
 
Robert J. Sutcliffe is a director of our general partner and serves as the Chairman of the Conflicts Committee and a member of the Audit Committee. He is a lawyer and business advisor based in Los Angeles and is the Managing Director of Craftsman Capital Advisors LLC, a private financial advisory and business consulting firm specializing in the representation of entrepreneurs and venture investors. Mr. Sutcliffe was, until 1989, a partner and chairman of the corporate practice group in the Los Angeles office of Brobeck, Phleger & Harrison, where his practice focused on venture capital, corporations and securities. He then served as Congressional Chief of Staff to the Honorable Christopher Cox of California until 1990. During the past five years, Mr. Sutcliffe served as a director of Innovative Card Technologies, Inc., a public company that develops technologies to enhance payment card functionality, and as non-executive Chairman of Miravant Medical Technologies, a pharmaceutical development company.  Mr. Sutcliffe received a B.A. in political science and international relations from the University of California, Los Angeles and a J.D. from Harvard Law School.  It was determined that Mr. Sutcliffe should serve as a director of our general partner because of his experience as an advisor providing financial and business consulting services and because of his legal background.
 
Don A. Turkleson is a director of our general partner.  He is Chief Financial Officer of Laurus Energy, Inc., a privately held underground coal gasification company.  He became Senior Vice President of Cheniere in May 2004, and served as Treasurer and Secretary of Cheniere until December 2004 and September 2006, respectively.  He served as Senior Vice President and Chief Financial Officer through March 2009.  Prior to joining Cheniere in 1997, Mr. Turkleson was employed by PetroCorp Incorporated from 1983 to 1996, as Controller until 1986 and then as Vice President-Finance, Secretary and Treasurer.  From 1975 to 1983, he worked as a Certified Public Accountant in the natural resources division of Arthur Andersen & Co. in Houston.  Mr. Turkleson received a B.S. in accounting from Louisiana State University.  It was determined that Mr. Turkleson should serve as a director of our general partner because of his experience and insight as the former Chief Financial Officer of Cheniere, Cheniere GP and the general
 
 
65
 

partner of Sabine Pass LNG, L.P.  and his background as a Certified Public Accountant.  Mr. Turkleson is a director and past Chairman of the Board of Neighborhood Centers, Inc., a nonprofit organization.  He has not held any other directorship positions in the past five years.
 
Walter L. Williams is a director of our general partner. Mr. Williams served as Vice Chairman of the board of directors of Cheniere from June 1999 until June 2008. He served as President and Chief Executive Officer of Cheniere from September 1997 until June 1999 and as Vice Chairman of the board of directors of Cheniere from July 1996 until September 1997. Prior to joining Cheniere, Mr. Williams spent 32 years as a founder and later Chairman and Chief Executive Officer of Texoil Company, a publicly-held Gulf Coast exploration and production company. Prior to that time, he was an independent petroleum consultant. Mr. Williams received a B.S. in petroleum engineering from Texas A&M University and is a Registered Engineer in Louisiana and Texas. It was determined that Mr. Williams should serve as a director of our general partner because of his combined knowledge and expertise of Cheniere and its subsidiaries based on his long history with Cheniere serving as former Chief Executive Officer of the Company for two years and serving as Vice Chairman of the Board of Directors for over 12 twelve years.  Mr. Williams currently serves on the Dwight Look College of Engineering Advisory Council at Texas A&M University. Mr. Williams has not held any other directorship positions in the past five years.
 
Code of Ethics
 
Our Code of Business Conduct and Ethics covers a wide range of business practices and procedures and furthers our fundamental principles of honesty, loyalty, fairness and forthrightness. The Code of Business Conduct and Ethics was approved by the directors of our general partner. Our Code of Business Conduct and Ethics is posted at www.cheniereenergypartners.com. We also intend to post any changes to or waivers of our Code of Business Conduct and Ethics for the executive officers of our general partner on our website.
 
Section 16(a) Beneficial Ownership Reporting Compliance
 
Section 16 of the Exchange Act requires the directors and executive officers of our general partner and persons who own more than 10% of a registered class of our equity securities to file initial reports of ownership and reports of changes in ownership with the SEC. Such persons are required by SEC regulation to furnish us with copies of all Section 16(a) forms they file. Based solely on our review of the copies of such forms furnished to us and written representations from the directors and executive officers of our general partner, we believe that all Section 16(a) filing requirements were met during 2009 in a timely manner.
 
ITEM 11. EXECUTIVE COMPENSATION
 
Compensation Discussion and Analysis
 
Our general partner has paid no cash compensation to its executive officers since its inception. All of the executive officers of our general partner are also executive officers of Cheniere. Cheniere compensates these officers for the performance of their duties as executive officers of Cheniere, which includes managing our partnership. Cheniere does not allocate this compensation between services for us and services for Cheniere and its affiliates. Instead, an affiliate of Cheniere provides us various general and administrative services, such as technical, commercial, regulatory, financial, accounting, treasury, tax and legal staffing and related support services, pursuant to a services agreement for which we pay a non-accountable administrative fee of $10 million per year, subject to adjustment for inflation. For a description of the services agreement, see Note 13 of our Notes to Consolidated Combined Financial Statements in Part II, Item 8. of this annual report on Form 10-K.
 
In 2007, the board of directors of our general partner adopted the Cheniere Energy Partners, L.P. Long-Term Incentive Plan for employees, consultants and directors of our general partner, employees of its affiliates and consultants to its subsidiaries. The purpose of the plan is to enhance attraction and retention of qualified individuals who are essential for the successful operation of our partnership and to encourage them to align their interests with our interests through an equity ownership stake in us. The plan allows for the grant of options, restricted units, phantom units and unit appreciation rights. Up to 1,250,000 units may be granted under the plan. The only awards that have been granted under the plan have been made to the board of directors of our general partner in the form of phantom units to be settled in cash over a four-year vesting period.
 
Compensation Committee Report
 
As discussed above, the board of directors of our general partner does not have a compensation committee. In fulfilling its responsibilities, the board of directors of our general partner, acting in lieu of a compensation committee, has reviewed and discussed the Compensation Discussion and Analysis with management. Based on this review and discussion, the board of directors of our general partner recommended that the Compensation Discussion and Analysis be included in this annual report on Form 10-K.

 
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By the members of the board of directors of our general partner:
 
Charif Souki
R. Keith Teague
Meg A. Gentle
James D. Bennett
Mike Bock
Lon McCain
Robert J. Sutcliffe
Don A. Turkleson
Walter L. Williams
 
Compensation Committee Interlocks and Insider Participation
 
As discussed above, the board of directors of our general partner does not have a compensation committee. If any compensation is to be paid to our officers, the compensation would be reviewed and approved by the entire board of directors of our general partner because they perform the functions of a compensation committee. None of the directors or executive officers of our general partner served as a member of a compensation committee of another entity that has or has had an executive officer who served as a member of the board of directors of our general partner during 2009.
 
Director Compensation
 
On May 29, 2007, the board of directors of our general partner approved an annual fee of $50,000 to each non-management director of our general partner for services as a director. Also approved were annual fees of $30,000 for the chairman of the audit committee; $15,000 for the members of the audit committee other than the chairman; and $5,000 for the chairman of the conflicts committee. All directors’ fees are pro-rated from the date of election to the board and are payable quarterly. On May 29, 2007 (the “Grant Date”), the board of directors of the general partner also granted Lon McCain and Robert Sutcliffe 12,000 phantom units pursuant to the terms of the Cheniere Energy Partners, L.P. Long-Term Incentive Plan. Mr. Bennett and Mr. Bock were elected to the board of directors of our general partner on August 15, 2008 and June 10, 2009, respectively. Mr. Williams and Mr. Turkleson became non-management directors of our general partner effective August 1, 2008 and June 1, 2009, respectively.  In addition to the annual fees paid to the non-management directors, Messrs. Bennett, Bock, Williams and Turkleson each received 12,000 phantom units. The grants have the same terms as those grants made to Messrs. McCain and Sutcliffe, except that the Grant Date for each grant is as follows: September 10, 2008 for Mr. Williams, December 10, 2008 for Mr. Bennett and June 10, 2009 for Messrs. Bock and Turkleson.  Each director will receive an additional 3,000 phantom units annually on each anniversary of the Grant Date. Vesting will occur for one-fourth of the phantom units on each anniversary of the Grant Date beginning on the first anniversary of the Grant Date. Upon vesting, the phantom units will be payable in cash in an amount equal to the fair market value of a common unit on such date. The directors receive no distributions, and no distributions accrue, on the outstanding phantom units.
 
Each director will be fully indemnified by us for actions associated with being a director to the extent permitted under Delaware law.
 
 
67
 

The following table shows the compensation of the board of directors of our general partner for the 2009 fiscal year:  

Name
  
Fees
Earned
or Paid
in Cash
  
Unit
Awards (1)
  
Option
Awards
  
Non-Equity
Incentive Plan
Compensation
  
Change in
Pension Value
and
Nonqualified
Deferred
Compensation
Earnings
  
All Other
Compensation
  
Total
Charif Souki (2)
  
$
—  
  
$
—  
  
$
—  
  
$
—  
  
$
—  
  
$
—  
  
$
—  
R. Keith Teague(2)
    
—  
    
—  
    
—  
    
—  
    
—  
    
—  
    
—  
Meg A. Gentle (2)
    
—  
    
—  
    
—  
    
—  
    
—  
    
—  
    
—  
James D. Bennett (3)
    
62,500
    
32,100
    
—  
    
—  
    
—  
    
—  
    
94,600
Mike Bock (4)
    
32,500
    
93,600
    
—  
    
—  
    
—  
    
—  
    
126,100
Lon McCain (5)
    
80,000
    
22,320
    
—  
    
—  
    
—  
    
—  
    
102,320
Robert J. Sutcliffe (6)
    
70,000
    
22,320
    
—  
    
—  
    
—  
    
—  
    
 92,320
Don A. Turkleson (7)
    
25,000
    
93,600
    
—  
    
—  
    
—  
    
665
    
119,265
Walter L. Williams (8)
    
50,000
    
26,520
    
—  
    
—  
    
—  
    
11,556
    
88,076
 
(1)
Reflects aggregate grant date fair value.  The phantom units are to be settled in cash. The units are valued using the closing unit price on the date of grant and are revalued on a quarterly basis through the date of vesting.
(2)
Charif Souki, Keith Teague and Meg Gentle are executive officers of our general partner and are also executive officers of Cheniere. Cheniere compensates these officers for the performance of their duties as executive officers of Cheniere, which includes managing our partnership. They do not receive additional compensation for service as directors.
(3)
Mr. Bennett was granted 3,000 phantom units in 2009 with a grant date fair value of $32,100. As of December 31, 2009, he held a total of 12,000 phantom units.  Mr. Bennett disclaims beneficial ownership of these units.  Mr. Bennett is an employee of GSO Capital Partners LP or one of its affiliates (“GSO”).  Under the terms of such employment, Mr. Bennett is required to transfer to GSO or its clients, as applicable, any and all compensation received in connection with his directorship for any portfolio companies managed by GSO.  GSO received $32,100 in cash upon the vesting of Mr. Bennett’s 3,000 phantom units in December 2009.
(4)
Mr. Bock was granted 12,000 phantom units in 2009 with a grant date fair value of $93,600. As of December 31, 2009, he held a total of 12,000 phantom units.
(5)
Mr. McCain was granted 3,000 phantom units in 2009 with a grant date fair value of $22,320. As of December 31, 2009, he held a total of 11,250 phantom units. Mr. McCain received $27,900 in cash upon the vesting of 3,750 phantom units in May 2009.
(6)
Mr. Sutcliffe was granted 3,000 phantom units in 2009 with a grant date fair value of $22,320. As of December 31, 2009, he held a total of 11,250 phantom units. Mr. Sutcliffe received $27,900 in cash upon the vesting of 3,750 phantom units in May 2009.
(7)
Mr. Turkleson became a non-employee director, effective as of June 1, 2009, and was granted 12,000 phantom units in 2009 with a grant date fair value of $93,600.  As of December 31, 2009, he held a total of 12,000 phantom units.  Mr. Turkleson also had use of a blackberry provided by Cheniere during 2009.  The blackberry expense was approximately $665.
(8)
Mr. Williams was granted 3,000 phantom units in 2009 with a grant date fair value of $26,520. As of December 31, 2009, he held a total of 12,000 phantom units. Mr. Williams received $26,520 in cash upon the vesting of 3,000 phantom units in September 2009.  Mr. Williams also had use of an office, parking space, laptop and blackberry at Cheniere’s headquarters during 2009. The pro rata amount of office lease expense related to that space was approximately $3,308.  The parking expense was approximately $3,248 and the laptop blackberry expense was approximately $5,000.
 
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT, AND RELATED UNITHOLDER MATTERS
 
The limited partner interest in our partnership is divided into units. As of February 15, 2010, there were 26,416,357 common units outstanding and 135,383,831 subordinated units outstanding. The following table sets forth the beneficial ownership of our units owned of record and beneficially as of February 15, 2010 by:
 
 
•
each person who beneficially owns more than 5% of the units;  
 
•
each of the directors of our general partner;  
 
•
each of the executive officers of our general partner; and  
 
•
all directors and executive officers of our general partner as a group.
 
The amounts and percentage of units beneficially owned are reported on the basis of regulations of the SEC governing the determination of beneficial ownership of securities. Under the rules of the SEC, a person is deemed to be a “beneficial owner” of a security if that person has or shares “voting power,” which includes the power to vote or to direct the voting of such security, or
 
 
68
 

“investment power,” which includes the power to dispose of or to direct the disposition of such security. A person is also deemed to be a beneficial owner of any securities of which that person has a right to acquire beneficial ownership within 60 days. Under these rules, more than one person may be deemed a beneficial owner of the same securities, and a person may be deemed a beneficial owner of securities as to which he has no economic interest.
 
Except as indicated by footnote, the persons named in the table below have sole voting and investment power with respect to all units shown as beneficially owned by them, subject to community property laws where applicable. The address for the beneficial owners listed below is 700 Milam Street, Suite 800, Houston, Texas 77002.
 
Name of Beneficial Owner
Common
Units
Beneficially
Owned
Percentage
of
Common
Units
Beneficially
Owned
Subordinated
Units
Beneficially
Owned
Percentage
Of
Subordinated
Units
Beneficially
Owned
Percentage
of Total
Equity
Securities
Beneficially
Owned
Cheniere Energy, Inc. (1)(2)
10,891,357
41%
135,383,831
100%
89%
Cheniere LNG Holdings, LLC (2)(3)
10,891,357
41%
135,383,831
100%
89%
Cheniere Subsidiary Holdings, LLC (2)(3)
—  
—  
135,383,831
100%
82%
Cheniere Common Units Holding, LLC (2)(3)
10,891,357
41%
—  
100%
 7%
Charif Souki (4)
373,496
1%
—  
—  
*
R. Keith Teague
—  
—  
—  
—  
—  
Meg A. Gentle
8,035
*
—  
—  
*
James D. Bennett
—  
 —  
—  
 —   —  
Mike Bock
—  
—  
—  
—  
—  
Lon McCain
—  
—  
—  
—  
—  
Robert J. Sutcliffe
—  
—  
—  
—  
—  
Don A. Turkleson
25,000
*
—  
—  
*
Walter L. Williams
15,388
*
—  
—  
—  
All executive officers and directors as a group (9 persons)
421,919
1%
—  
—  
*
 
 *
Less than 1%
(1)
Cheniere Energy, Inc. is the ultimate parent company of Cheniere LNG Holdings, LLC, Cheniere Subsidiary Holdings, LLC and Cheniere Common Units Holding, LLC and may, therefore, be deemed to beneficially own the units held by Cheniere LNG Holdings, LLC, Cheniere Subsidiary Holdings, LLC and Cheniere Common Units Holding, LLC.
(2)
Cheniere LNG Holdings, LLC owns 100% of the equity interests in our general partner and an 89% limited partner interest in us either directly or through Cheniere Subsidiary Holdings, LLC and Cheniere Common Units Holding, LLC, each a wholly-owned subsidiary, and may, therefore, be deemed to beneficially own the units held by Cheniere Subsidiary Holdings, LLC and Cheniere Common Units Holding, LLC.
(3)
All of Cheniere LNG Holdings, LLC’s subordinated units are pledged as collateral to The Bank of New York Mellon, as administrative agent under the Credit Agreement, dated May 31, 2007. All of Cheniere LNG Holdings, LLC’s common units are pledged as collateral to The Bank of New York Mellon, as collateral agent, under the 2008 Convertible Loans.
(4)
Mr. Souki holds 90,396 units directly and his wife owns 283,100 units.
 
Equity Compensation Plan Information
 
In 2007, the board of directors of our general partner adopted the Cheniere Energy Partners, L.P. Long-Term Incentive Plan. The following table provides certain information as of December 31, 2009 with respect to this plan:
 
Plan Category
  
Number of securities to be issued upon exercise of outstanding options, warrants and rights (1)
  
Weighted-average exercise price of outstanding
options, warrants and rights
  
Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in the first column)
Equity compensation plans approved by security holders
    
—  
    
N/A
    
—  
Equity compensation plans not approved by security holders
    
—  
    
N/A
    
1,250,000
Total
    
—  
    
N/A
    
1,250,000
 
(1)
The phantom units that have been granted are payable in cash at the time of vesting in an amount equal to the fair market value of a common unit on such date.
 
 
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For more information regarding the Long-Term Incentive Plan, see “Compensation Discussion and Analysis” in Item 11 of this annual report on Form 10-K.
 
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
 
Related-Party Transactions

Prior to the completion of our initial public offering of common units in 2007, the managers of our general partner approved the distributions and payments to be made to our general partner and its affiliates in connection with our ongoing operations and, in the event of, our liquidation. During our operational stage, we will generally make cash distributions to our unitholders, including our affiliates, as described in Part II, Item 5, of this annual report on Form 10-K. Upon our liquidation, our partners, including our general partner, will be entitled to receive liquidating distributions according to their respective capital account balances.
 
Under the audit committee charter, the audit committee of our general partner is required to review and approve all transactions or series of related financial transactions, arrangements or relationships between the partnership and any related-party, if the amount involved exceeds $120,000 and such transactions have not been reviewed by the conflicts committee of our general partner. The following related-party transactions are in addition to those related-party transactions described in Note 13 of our Notes to Consolidated Combined Financial Statements Part II, Item 8, of this annual report on Form 10-K. Except as described below, such related-party transactions were approved by the members of the board of directors of our general partner, which includes each member of the audit committee.
 
ISDA Master Agreement
 
In September 2007, Cheniere Marketing and Sabine Pass LNG entered into an International Swaps and Derivatives Association (“ISDA”) Master Agreement that provides Sabine Pass LNG with the ability to hedge its future price risk from time to time. The ISDA Master Agreement was entered into in the event Sabine Pass LNG chooses to hedge some of its LNG purchases or gas sales and elects to implement such hedges through Cheniere Marketing, which already has ISDA agreements in place with third parties and accounts with futures brokers. There are no current transactions under this agreement. No amounts were paid to Cheniere Marketing under this agreement during the fiscal years ended December 31, 2009 and 2008.
 
Operational Balancing Agreement
 
In December 2007, Sabine Pass LNG and Cheniere Creole Trail Pipeline, L.P. entered into an Operational Balancing Agreement that provides for the resolution of any operational imbalances (i) during the term of the agreement on an in-kind basis and (ii) upon termination of the agreement by cash-out at a rate equivalent to the average of the midpoint prices for Henry Hub, Louisiana pricing published in “Gas Daily’s-Daily Price Survey” for each day of the month following termination. This agreement became effective following the achievement of commercial operability of the Sabine Pass LNG receiving terminal in September 2008. Cheniere Creole Trail Pipeline, L.P. owed natural gas volumes valued at $197,628 and $53,862 to Sabine Pass LNG related to operational imbalances under this agreement at December 31, 2009 and 2008, respectively
 
LNG Terminal Export Agreement
 
In January 2010, Sabine Pass LNG and Cheniere Marketing entered into an LNG Terminal Export Agreement that provides Cheniere Marketing the ability to export LNG from the Sabine Pass LNG receiving terminal.  No amounts were paid to Sabine Pass LNG under this agreement during the fiscal years ended December 31, 2009 and 2008.

The following related-party transaction was not approved by the board of directors or audit committee of our general partner:
 
Letter Agreement regarding the Cooperative Endeavor Agreement and Payment in Lieu of Taxes Agreement

In July 2007, Sabine Pass LNG entered into Cooperative Endeavor Agreements with various Cameron Parish, Louisiana taxing authorities and a related agreement with Cheniere Marketing, each as described in Note 13 of our Notes to Consolidated Combined Financial Statements in Part II, Item 8, of this annual report on Form 10-K. During the years ended December 31, 2009 and 2008, Cheniere Marketing paid Sabine Pass LNG $2.4 million and $5.0 million, respectively, under the related agreement.
 
Independent Directors
 
Because we are a limited partnership, the NYSE Amex does not require our general partner’s board of directors to be composed of a majority of directors who meet the criteria for independence required by NYSE Amex. The board of our general partner has
 
70
 
 
determined that Mike Bock, Lon McCain and Robert Sutcliffe are independent directors in accordance with the following NYSE Amex US independence standards. A director would not be independent if any of the following relationships exists:
 
 
•
a director who is, or during the past three years was, employed by the partnership, general partner or by any parent or subsidiary of the partnership or general partner;  
 
•
a director who accepts, or has an immediate family member who accepts, any compensation from the partnership, general partner or by any parent or subsidiary of the partnership or general partner in excess of $120,000 during any twelve consecutive-month period or any of the past three fiscal years, other than compensation for board or committee services, or compensation paid to an immediate family member who is a non-executive employee of the partnership, general partner or by any parent or subsidiary of the partnership or general partner, among other exceptions;  
 
•
a director who is an immediate family member of an individual who is, or has been in any of the past three years, employed by the partnership, general partner or by any parent or subsidiary of the partnership or general partner as an executive officer;  
 
•
a director who is, or has an immediate family member who is, a partner in, or a controlling shareholder or an executive officer of, any organization to which the partnership, general partner or any parent or subsidiary of the partnership or general partner made, or from which the partnership, general partner or any parent or subsidiary of the partnership or general partner received, payments (other than those arising solely from investments in our common units or payments under non-discretionary charitable contribution matching programs) that exceed 5% of the organization’s consolidated gross revenues for that year, or $200,000, whichever is more, in any of the most recent three fiscal years;  
 
•
a director who is, or has an immediate family member who is, employed as an executive officer of another entity where at any time during the most recent three fiscal years any of the executive officers of the partnership, general partner or of any parent or subsidiary of the partnership or general partner serves on the compensation committee of such other entity; or  
 
•
a director who is, or has an immediate family member who is, a current partner of the outside auditor of the partnership, general partner or parent or subsidiary of the partnership or general partner, or was a partner or employee of the outside auditor of the partnership, general partner or any parent or subsidiary of the partnership or general partner who worked on our audit at any time during any of the past three years.

Mr. Bock served as a managing director at Merrill Lynch from December 2006 to April 2009 and, prior to that, he served as a principal and head of Corporate Finance at Petrie Parkman & Co.  Cheniere paid fees to Merrill Lynch in 2007 and 2008 and to Petrie Parkman in 2006; however, the payments did not exceed five percent of Merrill Lynch or Petrie Parkman’s gross revenues for those years.  The board of directors of our general partner reviewed the fees paid to Merrill Lynch and Petrie Parkman and has determined, after reviewing this information, that Mr. Bock is an independent director.   
 
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
 
Ernst & Young LLP served as our independent auditor for the fiscal years ending December 31, 2009 and 2008. The following table sets forth the fees paid to Ernst & Young LLP, for professional services rendered for 2009 and 2008:
 
   
Ernst & Young LLP
  
   
Fiscal 2009
    
Fiscal 2008
  
Audit Fees
   $ 800,000     $ 750,002  
Audit-Related Fees
     —        77,661  
Total
   $ 800,000     $ 827,663  
 
Audit Fees—Audit fees for 2009 and 2008 include attestation services and review of documents filed with the SEC in addition to audit, review and all other services performed to comply with generally accepted auditing standards.
 
Audit-Related Fees—Audit-related fees for 2008 were for services rendered in connection with the offering of securities in a private placement.
 
There were no tax or other fees in 2009 or 2008.
 
Auditor Pre-Approval Policy and Procedures
 
Under the audit committee’s charter, the audit committee is required to review and approve in advance all audit and lawfully permitted non-audit services to be provided by the independent accountants and the fees for such services. Pre-approval of non-audit services (other than review and attestation services) shall not be required if such services fall within exceptions established by the SEC. All audit and non-audit services provided to us during the fiscal year ended December 31, 2009 and 2008 were pre-approved.

 
71
 
 
PART IV
 
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
 
(a)
Financial Statements and Exhibits
 
(1)  
Financial Statements—Cheniere Energy Partners, L.P.:

40 
41 
43 
44 
45 
46 
47 
62 
 
(2)
Financial Statement Schedules:

76 
 
(3)
Exhibits
 
   
Exhibit No.
Description
   
2.1*
Contribution and Conveyance Agreement. (Incorporated by reference to Exhibit 10.4 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on March 26, 2007)
   
3.1*
Certificate of Limited Partnership of Cheniere Energy Partners, L.P. (Incorporated by reference to Exhibit 3.1 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on December 21, 2006)
   
3.2*
First Amended and Restated Agreement of Limited Partnership of Cheniere Energy Partners, L.P. (Incorporated by reference to Exhibit 3.1 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on March 26, 2007)
   
3.3*
Certificate of Formation of Cheniere Energy Partners GP, LLC. (Incorporated by reference to Exhibit 3.3 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on December 21, 2006)
   
3.4*
Second Amended and Restated Limited Liability Company Agreement of Cheniere Energy Partners GP, LLC. (Incorporated by reference to Exhibit 3.1 to Cheniere Energy Partners, L.P.’s Quarterly Report on Form 10-Q (SEC File No. 001-33366), filed on August 8, 2007)
   
4.1*
Form of common unit certificate. (Incorporated by reference to Exhibit A to Exhibit 3.2 above)
   
4.2*
Indenture, dated as of November 9, 2006, between Sabine Pass LNG, L.P., as issuer, and The Bank of New York, as trustee. (Incorporated by reference to Exhibit 4.1 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
4.3*
Form of 7.25% Senior Secured Note due 2013 (Included as Exhibit A1 to Exhibit 4.2 above)
   
4.4*
Form of 7.50% Senior Secured Note due 2016 (Included as Exhibit A1 to Exhibit 4.2 above)
   
10.1*
LNG Terminal Use Agreement, dated September 2, 2004, by and between Total LNG USA, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 15, 2004)
   
10.2*
Amendment of LNG Terminal Use Agreement, dated January 24, 2005, by and between Total LNG USA, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.40 to Cheniere Energy, Inc.’s Annual Report on Form 10-K (SEC File No. 001-16383), filed on March 10, 2005)
   
10.3* Omnibus Agreement, dated September 2, 2004, by and between Total LNG USA, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.2 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 15, 2004)

 
72
 


Exhibit No.
Description
 
 
10.4*
Guaranty, dated as of November 9, 2004, by Total S.A. in favor of Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.3 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001 16383), filed on November 15, 2004)
   
10.5*
LNG Terminal Use Agreement, dated November 8, 2004, between Chevron U.S.A. Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.4 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 15, 2004)
   
10.6*
Amendment to LNG Terminal Use Agreement, dated December 1, 2005, by and between Chevron U.S.A., Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.28 to Sabine Pass LNG, L.P.’s Registration Statement on Form S-4 (SEC File No. 333-138916), filed on November 22, 2006)
   
10.7*
Omnibus Agreement, dated November 8, 2004, between Chevron U.S.A., Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.5 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 15, 2004)
   
10.8*
Guaranty Agreement, dated as of December 15, 2004, from ChevronTexaco Corporation to Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.12 to Sabine Pass LNG, L.P.’s Registration Statement on Form S-4 (SEC File No. 333-138916), filed on November 22, 2006)
   
10.9*
Amended and Restated Terminal Use Agreement, dated November 9, 2006, by and between Cheniere Marketing, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.6 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.10*
Amendment of LNG Terminal Use Agreement, dated June 25, 2007, by and between Cheniere Marketing, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on June 26, 2007)
   
10.11*
Cooperative Endeavor Agreement & Payment in Lieu of Tax Agreement, dated October 23, 2007 (amending the Amended and Restated Terminal Use Agreement, dated November 9, 2006, by and between Cheniere Marketing, Inc. and Sabine Pass LNG, L.P.). (Incorporated by reference to Exhibit 10.7 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 6, 2007)
   
10.12*
LNG Lease Agreement, dated June 24, 2008, between Cheniere Marketing, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.7 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on August 11, 2008)
   
10.13*
Guarantee Agreement, dated as of November 9, 2006, by Cheniere Energy, Inc. (Incorporated by reference to Exhibit 10.7 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.14*
Collateral Trust Agreement, dated November 9, 2006, by and among Sabine Pass LNG, L.P., The Bank of New York, as collateral trustee, Sabine Pass LNG-GP, Inc. and Sabine Pass LNG-LP, LLC. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.15*
Amended and Restated Parity Lien Security Agreement, dated November 9, 2006, by and between Sabine Pass LNG, L.P. and The Bank of New York, as collateral trustee. (Incorporated by reference to Exhibit 10.2 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.16*
Third Amended and Restated Multiple Indebtedness Mortgage, Assignment of Rents and Leases and Security Agreement, dated November 9, 2006, between the Sabine Pass LNG, L.P. and The Bank of New York, as collateral trustee. (Incorporated by reference to Exhibit 10.3 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.17* Amended and Restated Parity Lien Pledge Agreement, dated November 9, 2006, by and among Sabine Pass LNG, L.P., Sabine Pass LNG-GP, Inc., Sabine Pass LNG-LP, LLC and The Bank of New York, as collateral trustee. (Incorporated by reference to Exhibit 10.4 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.18* Security Deposit Agreement, dated November 9, 2006, by and among Sabine Pass LNG, L.P., The Bank of New York, as collateral trustee, and The Bank of New York, as depositary agent. (Incorporated by reference to Exhibit 10.5 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on November 16, 2006)
   
10.19*
 Letter Agreement, dated May 8, 2007, between Cheniere Marketing, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.8 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed
   

 
73
 
 
Exhibit No.
Description
 
 
   on May 8, 2007), and Form of LNG Terminal Use Agreement between J&S Cheniere S.A. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit B of Exhibit 8.2(a) of Exhibit 10.8 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on May 8, 2007)
   
10.20*
Operation and Maintenance Agreement, dated February 25, 2005, between Sabine Pass LNG, L.P. and Cheniere LNG O&M Services, L.P. (Incorporated by reference to Exhibit 10.5 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on March 2, 2005)
   
10.21*
Assignment, Assumption, Consent and Release Agreement, dated March 26, 2007, among Cheniere LNG O&M Services, L.P., Cheniere Energy Partners GP, LLC and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.53 to the Cheniere Energy Partners, L.P. Annual Report on Form 10-K (SEC File No. 001-33366) filed on February 27, 2009)
   
10.22*
Services and Secondment Agreement, dated March 26, 2007, between Cheniere LNG O&M Services, L.P. and Cheniere Energy Partners GP, LLC. (Incorporated by reference to Exhibit 10.2 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on March 26, 2007)
   
10.23*
CQP GP Consent and Agreement (Operation and Maintenance Agreement), dated August 15, 2008, among Cheniere LNG O&M Services, LLC, Cheniere Energy Partners GP, LLC and The Bank of New York Mellon. (Incorporated by reference to Exhibit 10.2 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 7, 2008)
   
10.24*
Sabine Consent and Agreement (Operation and Maintenance Agreement), dated August 15, 2008, among Cheniere Energy Partners GP, LLC, Sabine Pass LNG, L.P. and The Bank of New York Mellon. (Incorporated by reference to Exhibit 10.4 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 7, 2008)
   
10.25*
Management Services Agreement, dated February 25, 2005, between Sabine Pass LNG-GP, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.6 to Cheniere Energy, Inc.’s Current Report on Form 8-K (SEC File No. 001-16383), filed on March 2, 2005)
   
10.26*
Letter Agreement (Management Services Agreement), dated September 1, 2006, between Sabine Pass LNG-GP, Inc. and Cheniere LNG Terminals, Inc. (Incorporated by reference to Exhibit 10.29 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on February 14, 2007)
   
10.27*
Assignment, Assumption, Consent and Release Agreement (Management Services Agreement), dated August 15, 2008, between Sabine Pass LNG-GP, Inc., Cheniere LNG Terminals, Inc. and Sabine Pass LNG, L.P. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 7, 2008)
   
10.28*
Sabine Consent and Agreement (Management Services Agreement), dated August 15, 2008, among Cheniere LNG Terminals, Inc., Sabine Pass LNG, L.P. and The Bank of New York Mellon. (Incorporated by reference to Exhibit 10.5 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 7, 2008)
   
 
10.29*
  
Management and Administrative Services Agreement, dated March 26,2 007, between Cheniere Energy Partners, L.P. and Cheniere LNG Terminals, Inc. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on March 26, 2007)
   
 
10.30*
  
CQP Consent and Agreement (Management and Administrative Services Letter Agreement), dated August 15, 2008, among Cheniere LNG Terminals, Inc., Cheniere Energy Partners, L.P. and The Bank of New York Mellon. (Incorporated by reference to Exhibit 10.3 to Cheniere Energy, Inc.’s Quarterly Report on Form 10-Q (SEC File No. 001-16383), filed on November 7, 2008)
   
 
10.31*
  
Settlement and Purchase Agreement dated as of June 14, 2001, by and among Cheniere Energy, Inc., CXY Corporation, Crest Energy, L.L.C., Crest Investment Company and Freeport LNG Terminal, LLC, and two related letter agreements, each dated February 27, 2003. (Incorporated by reference to Exhibit 10.36 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on January 25, 2007)
   
 
10.32*
  
Letter regarding Assumption and Adoption of Obligations under Settlement and Purchase Agreement, dated May 9, 2005, and Indemnification Agreement, dated May 9, 2005, by Cheniere Energy, Inc. (Incorporated by reference to Exhibit 10.29 to Sabine Pass LNG, L.P.’s Registration Statement on Form S-4/A (SEC File No. 333-138916), filed on January 10, 2007)
   
 
10.33*†
  
Cheniere Energy Partners, L.P. 2007 Long-Term Incentive Plan. (Incorporated by reference to Exhibit 10.3 to
   

 
74
 


Exhibit No.
Description
 
 
  Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on March 26, 2007)
   
10.34*†
Form of Restricted Units Agreement for employees, consultants and directors (three-year). (Incorporated by reference to Exhibit 10.39 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.35*†
Form of Restricted Units Agreement for employees, consultants and directors (four-year). (Incorporated by reference to Exhibit 10.40 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.36*†
Form of Director Units Option Agreement for employees and consultants (four-year). (Incorporated by reference to Exhibit 10.41 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.37*†
Form of Units Option Agreement for employees and consultants (three-year). (Incorporated by reference to Exhibit 10.42 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.38*†
Form of Units Option Agreement for employees and consultants (four-year). (Incorporated by reference to Exhibit 10.43 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.39*†
Form of Phantom Units Agreement for employees, consultants and directors (four-year). (Incorporated by reference to Exhibit 10.44 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.40*†
Form of Phantom Units Agreement for employees, consultants and directors (three-year). (Incorporated by reference to Exhibit 10.45 to Cheniere Energy Partners, L.P.’s Registration Statement on Form S-1 (SEC File No. 333-139572), filed on March 2, 2007)
   
10.41*†
Form of Phantom Units Agreement. (Incorporated by reference to Exhibit 10.2 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on June 4, 2007)
   
10.42*†
Summary of Compensation to Independent Directors. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on June 4, 2007)
   
10.43*†
Form of Indemnification Agreement for officers and/or directors of Cheniere Energy Partners GP, LLC. (Incorporated by reference to Exhibit 10.1 to Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on April 6, 2009)
 
21.1
Subsidiaries of Cheniere Energy Partners, L.P.
   
23.1
Consent of Ernst & Young LLP
   
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
 
*
Incorporated by reference
†
Management contract or compensatory plan or arrangement
 

 
75
 

SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF REGISTRANT—

CHENIERE ENERGY PARTNERS, L.P.
 
CONDENSED BALANCE SHEET
(in thousands)
 
   
December 31,
  
   
2009
    
2008
  
ASSETS
            
CURRENT ASSETS
            
Cash and cash equivalents
   $ 130     $ 6  
Interest receivable
     —         1,726  
Prepaid expenses and other
     242       —    
Total current assets
     372       1,732  
Non-current restricted cash and cash equivalents
     —         11,928  
Non-current restricted treasury securities
     —         20,829  
Total assets
   $ 372     $ 34,489  
LIABILITIES AND STOCKHOLDERS’ EQUITY
                
CURRENT LIABILITIES
   $ 170     $ 177  
LONG-TERM DEBT—RELATED PARTY
     —         2,347  
INVESTMENT IN AND EQUITY IN LOSSES OF AFFILIATES
     480,529       383,650  
COMMITMENTS AND CONTINGENCIES
     —         —    
STOCKHOLDERS’ (DEFICIT) EQUITY
     (480,327 )     (351,685 )
Total liabilities and stockholders’ equity
   $ 372     $ 34,489  


See accompanying notes to condensed financial statements.
 

 
76
 

SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF REGISTRANT—

CHENIERE ENERGY PARTNERS, L.P.
 
CONDENSED STATEMENT OF OPERATIONS
(in thousands)
 
   
Year Ended December 31,
  
   
        2009
    
        2008
    
        2007
  
Revenues    $ —       $  —       $ —    
Operating costs and expenses
     12,286       1,742       882  
Loss from operations
     (12,286 )     (1,742 )     (882 )
Interest expense, net
     (13 )     (114 )     (13 )
Interest income
     406       2,225       3,308  
Other income
     —         234       —    
Equity income (losses) of affiliates
     198,805       (78,947 )     (51,365 )
Net income (loss)
   $ 186,912     $ (78,344 )   $ (48,952 )


See accompanying notes to condensed financial statements.
 
 
77
 

SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF REGISTRANT—

CHENIERE ENERGY PARTNERS, L.P.
 
CONDENSED STATEMENT OF CASH FLOWS
(in thousands)
 
   
Year Ended December 31,
  
   
2009
    
2008
    
2007
  
NET CASH USED IN OPERATING ACTIVITIES
   $ (10,411 )   $ (1,707 )   $ (621 )
                         
CASH FLOWS FROM INVESTING ACTIVITIES:
                        
Iinvestment in restricted cash and cash equivalents
     —         —         (10,851 )
Investment in restricted U.S. Treasury securities
     —         —         (63,923 )
NET CASH USED IN INVESTING ACTIVITIES
     —         —         (74,774 )
                         
CASH FLOWS FROM FINANCING ACTIVITIES:
                        
Distributions received from Sabine Pass LNG, L.P.
     295,684       —         —    
Distributions to owners
     (280,674 )     (45,824 )     (23,668 )
Use of restricted cash and cash equivalents
     32,757       45,824       —    
Special rights adjustment
     (34,879 )     —         —    
Repayment of long-term note—affiliate
     (2,467 )     —         —    
Borrowings under long-term note—affiliate
     114       1,708       632  
Proceeds from issuance of common units
     —         —         98,442  
Other
     —         (3 )     (3 )
NET CASH PROVIDED BY FINANCING ACTIVITIES
     10,535       1,705       75,403  
                         
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
     124       (2 )     8  
CASH AND CASH EQUIVALENTS—BEGINNING OF YEAR
     6       8       —    
CASH AND CASH EQUIVALENTS—END OF YEAR
   $ 130     $ 6     $ 8  
 

See accompanying notes to condensed financial statements.
 
 
78
 

CHENIERE ENERGY PARTNERS, L.P.
 
NOTES TO CONDENSED FINANCIAL STATEMENTS
 
NOTE 1—Summary of Significant Accounting Policies
 
The condensed financial statements represent the financial information required by Securities and Exchange Commission Regulation S-X 5-04 for Cheniere Energy Partners, L.P. (“Cheniere Energy Partners”).
 
In the condensed financial statements, Cheniere Energy Partners’ investments in affiliates are presented under the equity method of accounting. Under this method, the assets and liabilities of affiliates are not consolidated. The investments in net assets of the affiliates are recorded in the balance sheets. The gain/(loss)loss from operations of the affiliates is reported on a net basis as equity in net gains/(losses) of affiliates.
 
A substantial amount of Cheniere Energy Partners’ operating, investing, and financing activities are conducted by its affiliates. The condensed financial statements should be read in conjunction with Cheniere Energy Partners’ Consolidated Combined Financial Statements in Part II, Item 8. of this annual report on Form 10-K.
 
 NOTE 2—SUPPLEMENTAL CASH FLOW INFORMATION AND DISCLOSURES OF NON-CASH TRANSACTIONS
 
   
Year Ended December 31,
  
   
2009
    
2008
    
2007
  
   
(in thousands)
Non-cash capital contributions (1)
   $ 198,805     $ (78,947 )   $ (51,365 )
 
(1)
Amounts represent equity gains (losses) of affiliates not funded by Cheniere Energy Partners.
 

 
79
 

SIGNATURES
 
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
   
CHENIERE ENERGY PARTNERS, L.P.
By:
Cheniere Energy Partners GP, LLC,
its general partner
   
By:
/s/    CHARIF SOUKI        
 
Charif Souki
Chief Executive Officer and
Chairman of the Board
  
 
 
Date: February 25, 2010
 
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the general partner of the registrant and in the capacities and on the dates indicated.


Signature
Title
Date
     
/s/    CHARIF SOUKI
Chief Executive Officer & Chairman of the Board
(Principal Executive Officer)
February 25, 2010
Charif Souki
     
/s/    R. KEITH TEAGUE
President and Chief Operating Officer,
Director (Principal Operating Officer)
February 25, 2010
R. Keith Teague
     
/s/    Meg A. Gentle
Senior Vice President & Chief Financial Officer,
Director (Principal Financial Officer))
February 25, 2010
Meg A. Gentle
     
/s/    JERRY D. SMITH
Chief Accounting Officer
(Principal Accounting Officer)
February 25, 2010
Jerry D. Smith
     
/s/    JAMES D. BENNETT 
Director
February 25, 2010
James D. Bennett
     
/s/    Michael E. Bock
Director
February 25, 2010
Michael E. Bock
    
     
/s/    LON MCCAIN 
Director
February 25, 2010
Lon McCain
    
     
/s/    ROBERT J. SUTCLIFFE 
Director
February 25, 2010
Robert J. Sutcliffe
    
     
/s/    ROBERT J. SUTCLIFFE 
Director
February 25, 2010
Robert J. Sutcliffe
    
     
 /s/    WALTER L. WILLIAMS  Director February 25, 2010
Walter L. Williams    
     
 /s/    Don A. Turkleson    Director February 25, 2010
Don A. Turkleson
 
 
 
 
 
80