x
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ANNUAL REPORT PURSUANT TO SECTION
13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF
1934
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¨
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TRANSITION
REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF
1934
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Delaware
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20-5913059
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(State
or other jurisdiction of incorporation or organization)
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(I.R.S.
Employer Identification No.)
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700
Milam Street, Suite 800
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Houston,
Texas
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77002
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(Address
of principal executive offices)
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(Zip
code)
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Common
Units Representing Limited
Partner
Interests
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NYSE
Amex Equities
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(Title
of Class)
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(Name
of each exchange on which
registered)
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Large accelerated filer ¨
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Accelerated filer x
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Non-accelerated filer ¨
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Smaller reporting company ¨
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(Do
not check if a smaller reporting company)
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statements
regarding our ability to pay distributions to our
unitholders;
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our
expected receipt of cash distributions from Sabine Pass LNG,
L.P.;
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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;
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statements
regarding any financing transactions or arrangements, or ability to enter
into such transactions or
arrangements;
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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;
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statements
regarding counterparties to our TUAs, construction contracts and other
contracts;
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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;
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statements
regarding legislative, governmental, regulatory, administrative or other
public body actions, requirements, permits, investigations, proceedings or
decisions; and
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any
other statements that relate to non-historical or future
information.
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Bcf means billion cubic
feet;
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Bcf/d means billion
cubic feet per day;
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EPC means engineering,
procurement and construction;
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EPCM means engineering,
procurement, construction and
management;
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LNG means liquefied
natural gas; and
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TUA means terminal use
agreement.
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successfully
managing the operation of the Sabine Pass LNG receiving terminal;
and
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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.
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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
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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.
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Risks
Relating to Our Financial Matters;
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Risks
Relating to Our Business;
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Risks
Relating to Our Cash Distributions;
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Risks
Relating to an Investment in Us and Our Common Units;
and
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Risks
Relating to Tax Matters.
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limiting
our ability to attract customers;
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limiting
our ability to compete with other companies that are not as highly
leveraged;
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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;
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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;
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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
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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.
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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;
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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
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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.
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incur
additional indebtedness;
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create
liens on our assets; and
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engage
in sale and leaseback transactions and mergers or acquisitions and to make
equity investments.
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performing
below expected levels of
efficiency;
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breakdown
or failures of equipment or
systems;
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operational
errors by vessel or tug operators or
others;
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operational
errors by us or any contracted facility operator or
others;
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labor
disputes; and
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weather-related
interruptions of operations.
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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;
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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
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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.
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additions
to competitive regasification capacity in North America, Europe, Asia and
other markets, which could divert LNG from the Sabine Pass LNG receiving
terminal;
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insufficient
LNG liquefaction capacity
worldwide;
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insufficient
LNG tanker capacity;
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reduced
demand and lower prices for natural
gas;
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increased
natural gas production deliverable by pipelines, which could suppress
demand for LNG;
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cost
improvements that allow competitors to offer LNG regasification services
at reduced prices;
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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;
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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;
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adverse
relative demand for LNG in North America compared to other markets, which
may decrease LNG imports into North America;
and
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cyclical
trends in general business and economic conditions that cause changes in
the demand for natural gas.
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increased
construction costs;
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economic
downturns, increases in interest rates or other events that may affect the
availability of sufficient financing for LNG projects on commercially
reasonable terms;
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decreases
in the price of LNG and natural gas, which might decrease the expected
returns relating to investments in LNG
projects;
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the
inability of project owners or operators to obtain governmental approvals
to construct or operate LNG
facilities;
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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
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any
significant explosion, spill or similar incident involving an LNG
liquefaction facility or LNG
carrier.
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an
inadequate number of shipyards constructing LNG vessels and a backlog of
orders at these shipyards;
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political
or economic disturbances in the countries where the vessels are being
constructed;
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changes
in governmental regulations or maritime self-regulatory
organizations;
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work
stoppages or other labor disturbances at the
shipyards;
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bankruptcy
or other financial crisis of
shipbuilders;
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quality
or engineering problems;
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weather
interference or a catastrophic event, such as a major earthquake, tsunami
or fire; and
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shortages
of or delays in the receipt of necessary construction
materials.
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relatively
minor changes in the supply of, and demand for, natural gas in relevant
markets;
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political
conditions in international natural gas producing
regions;
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the
extent of domestic production and importation of natural gas in relevant
markets;
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the
level of demand for LNG and natural gas in relevant markets, including the
effects of economic downturns or
upturns;
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weather
conditions;
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the
competitive position of natural gas as a source of energy compared with
other energy sources; and
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the
effect of government regulation on the production, transportation and sale
of natural gas.
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we
are unable to identify attractive acquisition candidates or negotiate
acceptable purchase contracts with
them;
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we
are unable to obtain necessary governmental
approvals;
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we
are unable to obtain financing for the acquisitions on economically
acceptable terms, or at all;
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we
are unable to secure adequate customer commitments to use the acquired
facilities; or
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we
are outbid by competitors.
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an
inability to integrate successfully the businesses that we acquire with
our existing business;
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a
decrease in our liquidity by using a significant portion of our available
cash or borrowing capacity to finance the
acquisition;
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the
assumption of unknown liabilities;
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limitations
on rights to indemnity from the
seller;
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mistaken
assumptions about the cash generated, or to be generated, by the business
acquired or the overall costs of equity or
debt;
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the
diversion of management’s and employees’ attention from other business
concerns; and
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unforeseen
difficulties encountered in operating new business segments or in new
geographic areas.
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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;
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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;
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outstanding
principal on the Senior Notes then due and payable has been
paid;
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taxes
payable by Sabine Pass LNG or the guarantors of the Senior Notes and
permitted payments in respect of taxes have been paid;
and
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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.
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a
default for 30 days in the payment of interest on, or additional interest,
if any, with respect to, the Senior
Notes;
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a
failure to pay any principal of, or premium, if any, on the Senior
Notes;
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a
failure by Sabine Pass LNG to comply with various covenants in the Sabine
Pass Indenture;
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a
failure to observe any other agreement in the Sabine Pass Indenture beyond
any specified cure periods;
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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;
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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;
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a
failure of any material representation or warranty in the security
documents entered into in connection with the indenture to be
correct;
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the
Sabine Pass LNG receiving terminal project is abandoned;
or
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certain
events of bankruptcy or insolvency.
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make
certain investments;
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purchase,
redeem or retire equity interests;
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issue
preferred stock;
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sell
or transfer assets;
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incur
liens;
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enter
into transactions with affiliates;
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consolidate,
merge, sell or lease all or substantially all of its assets;
and
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enter
into sale and leaseback
transactions.
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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;
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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;
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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
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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..
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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:
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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;
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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;
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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;
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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”;
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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;
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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;
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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;
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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;
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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
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our
general partner decides whether to retain separate counsel, accountants or
others to perform services for us.
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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;
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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;
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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;
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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
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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.
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our
unitholders’ proportionate ownership interest in us will
decrease;
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the
amount of cash available per unit to pay distributions may decrease;
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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;
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the
ratio of taxable income to distributions may
increase;
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the
relative voting strength of each previously outstanding unit may be
diminished; and
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the
market price of the common units may
decline.
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our
quarterly distributions;
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our
quarterly or annual earnings or those of other companies in our
industry;
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actual
or potential non-performance by any customer under a
TUA;
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announcements
by us or our competitors of significant
contracts;
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changes
in accounting standards, policies, guidance, interpretations or
principles;
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general
economic conditions;
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the
failure of securities analysts to cover our common units or changes in
financial or other estimates by
analysts;
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future
sales of our common units; and
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other
factors described in these “Risk
Factors.”
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High
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Low
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Cash
Distributions
Per
Unit (1)
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||||||||||
Three
Months Ended
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March 31,
2008
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$ | 17.39 | $ | 14.85 | $ | 0.425 | ||||||
June 30,
2008
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16.14 | 8.69 | 0.425 | |||||||||
September 30,
2008
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10.21 | 6.95 | 0.425 | |||||||||
December 31,
2008
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6.98 | 3.71 | 0.425 | |||||||||
Three
Months Ended
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March 31,
2009
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7.10 | 4.32 | 0.425 | |||||||||
June 30,
2009
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7.99 | 6.03 | 0.425 | |||||||||
September 30,
2009
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9.95 | 6.95 | 0.425 | |||||||||
December 31,
2009
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13.30 | 9.27 | 0.425 |
(1)
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We
also paid cash distributions to subordinated unitholders and to our
general partner with respect to its 2% general partner
interest.
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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;
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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
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there
are no arrearages in payment of the initial quarterly distribution on the
common units.
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the
subordination period will end and each subordinated unit will immediately
convert into one common unit;
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any
existing arrearages in payment of the initial quarterly distribution on
the common units will be extinguished;
and
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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.
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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;
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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
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there
are no arrearages in payment of the initial quarterly distribution on the
common units.
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Total
Quarterly Distribution
Target
Amount
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Marginal
Percentage
Interest
Distributions
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Common
and Subordinated Unitholders
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General
Partner
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Initial
quarterly distribution
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$0.425
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98%
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2%
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First
Target Distribution
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Above
$0.425 up to $0.489
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98%
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2%
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Second
Target Distribution
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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%
|
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.
|
|
•
|
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
|
|
•
|
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.
|
|
•
|
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.
|
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
|
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
|
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.
|
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)
|
|
The
Board of Directors of Cheniere Energy Partners GP, LLC,
and
|
|
Unitholders
of Cheniere Energy Partners, L.P.
|
/s/ ERNST
& YOUNG LLP
|
ERNST &
YOUNG LLP
|
/s/ ERNST
& YOUNG LLP
|
ERNST &
YOUNG LLP
|
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
|
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
|