UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K/A
(AMENDMENT NO. 1)
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE
ACT OF 1934
OR
[_] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
FOR THE YEAR ENDED DECEMBER 31, 2000
Commission File No. 0-9092
CHENIERE ENERGY, INC.
(Exact name of registrant as specified in its charter)
DELAWARE 95-4352386
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
333 CLAY STREET, SUITE 3400 77002-4102
HOUSTON, TEXAS (Zip code)
(Address of principal executive offices)
Registrant's telephone number, including area code: (713) 659-1361
Securities registered pursuant to Section 12(b) of the Act:
None
Securities registered pursuant to Section 12(g) of the Act:
COMMON STOCK, $ 0.003 PAR VALUE
(Title of Class)
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 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/A OR ANY
AMENDMENT TO THIS FORM 10-K/A. [_]
THE AGGREGATE MARKET VALUE OF THE REGISTRANT'S COMMON STOCK HELD BY NON-
AFFILIATES OF THE REGISTRANT WAS APPROXIMATELY $25,260,770 AS OF MARCH 30, 2001
(BASED UPON THE MARCH 30, 2001 CLOSING MARKET PRICE OF SUCH COMMON STOCK AS
REPORTED ON THE AMERICAN STOCK EXCHANGE). 12,797,393 SHARES OF THE REGISTRANT'S
COMMON STOCK WERE OUTSTANDING AS OF MARCH 30, 2001.
DOCUMENTS INCORPORATED BY REFERENCE: PROXY STATEMENT FOR THE REGISTRANT'S ANNUAL
MEETING OF STOCKHOLDERS (TO BE FILED WITHIN 120 DAYS OF THE CLOSE OF THE
REGISTRANT'S FISCAL YEAR) IS INCORPORATED BY REFERENCE INTO PART III.
CHENIERE ENERGY, INC.
Index to Form 10-K/A
PART I.................................................................................................... 3
Items 1 and 2. Business and Properties.................................................................... 3
Item 3. Legal Proceedings................................................................................. 18
Item 4. Submission of Matters to a Vote of Security Holders............................................... 18
PART II................................................................................................... 19
Item 5. Market Price of and Dividends on the Registrant's Common Equity and Related Stockholder Matters... 19
Item 6. Selected Financial Data.......................................................................... 19
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations............ 21
Item 7A. Quantitative and Qualitative Disclosures About Market Risk...................................... 26
Item 8. Financial Statements and Supplementary Data....................................................... 27
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.............. 54
PART III.................................................................................................. 55
Items 10-13. (Incorporated by reference to Proxy Statement)............................................... 55
PART IV................................................................................................... 55
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K.................................. 55
SIGNATURES................................................................................................ 60
2
PART I
ITEMS 1. AND 2. BUSINESS AND PROPERTIES
GENERAL
Cheniere Energy, Inc., a Delaware corporation, is a Houston-based company
engaged in oil and gas exploration, development and exploitation. The terms
Cheniere and Company refer to Cheniere Energy, Inc. and its subsidiaries. The
Company evaluates and generates drilling prospects using a regional and
integrated approach with a large seismic database as a platform.
Cheniere has been publicly traded since July 3, 1996 under the name Cheniere
Energy, Inc. The Company's principal executive offices are located at 333 Clay
Street, Suite 3400, Houston, Texas 77002, and its telephone number is (713)
659-1361. Cheniere's internet website is located at www.cheniere.com.
On October 16, 2000 the Company's stockholders approved a one-for-four reverse
stock split. The reverse stock split became effective on October 18, 2000 and
reduced Cheniere's issued and outstanding shares from 43,989,572 shares to
approximately 10,997,393 shares. All historical share and per share data
appearing in this document have been restated to reflect the reverse stock
split.
As used in this Report, Mcf means thousand cubic feet, Mmcf means million cubic
feet, Bcf means billion cubic feet, Bbl means barrel or 42 U.S. gallons liquid
volume, Mbbl means thousand barrels, Mcfe means thousand cubic feet of natural
gas equivalent using the ratio of six Mcf of natural gas to one Bbl of crude
oil, condensate and natural gas liquids, Mmcfe means million cubic feet of
natural gas equivalent, Bcfe means billion cubic feet of natural gas equivalent,
and Mmbtu means million British thermal units. This Report includes various
other capitalized terms that are defined when first used.
GENERAL DEVELOPMENT OF BUSINESS
Cheniere Energy Operating Co., Inc. (Cheniere Operating) was incorporated in
Delaware in February 1996 for the purpose of engaging in the oil and gas
exploration business, initially on the Louisiana Gulf Coast. On July 3, 1996,
Cheniere Operating underwent a reorganization whereby Bexy Communications, Inc.,
a publicly held Delaware corporation (Bexy), received 100% of the outstanding
shares of Cheniere Operating, and the former stockholders of Cheniere Operating
received approximately 93% of the issued and outstanding Bexy shares. As a
result of the share exchange, a change in the control of the Company occurred.
The transaction was accounted for as a recapitalization of Cheniere Operating.
Bexy spun off its existing assets and liabilities to its original stockholders
and changed its name to Cheniere Energy, Inc. Cheniere Operating became a
wholly-owned subsidiary of the Company.
Cameron Project. In 1996, Cheniere entered into an exploration agreement with an
industry partner to acquire and process proprietary seismic data along the
transition zone in Cameron Parish, Louisiana, covering a 228-square- mile area
(the Cameron Project). The 228-square-mile survey was acquired jointly by
Cheniere and an industry partner, and initial processing was completed in 1997.
Interpretation of the data yielded drilling prospects located onshore and in the
state and federal waters of offshore Louisiana. Leasing activity occurred over
identified prospects throughout these areas and five prospects were drilled
during 1999. Leasing over additional prospects began in 2000 and continues. See
- --Exploration Programs.
Offshore Louisiana Area. In an effort to provide continued access to high
quality drilling prospects, the Company expanded beyond the Cameron Project and
into the shallow waters of the Gulf of Mexico. In 1999, Cheniere licensed 8,800
square miles of seismic data from Fairfield Industries (the Offshore Louisiana
Area). The Company also made the commitment to reprocess the entire 8,800
square-mile seismic database. On March 10, 2000, the Company entered into a
Joint Exploration Agreement with Samson Offshore Company (Samson), whereby
Samson acquired an option to participate at a 50% working interest level in any
prospects Cheniere generates within an area of mutual interest in the Gulf of
Mexico through September 2001.
On September 15, 2000 Cheniere reached an agreement (the Gryphon Transaction)
with Warburg, Pincus Equity Partners, L.P. (Warburg), a global private equity
fund based in New York, to fund exploration and development in the Offshore
Louisiana Area through a newly formed private corporation, Gryphon Exploration
Company (Gryphon). The Company contributed to Gryphon: (i) the Company's license
from Fairfield Industries to seismic data covering the Offshore Louisiana Area;
(ii) the Company's interest in the Joint Exploration Agreement with Samson,
(iii) certain offshore leases, including its Shark prospect on West Cameron
Block 49, and
3
(iv) certain other assets and liabilities, all in exchange for 100% of the
common stock of the subsidiary and cash. Warburg invested $25,000,000 and
received preferred stock, with an 8% accruing dividend, convertible into 63.2%
of Gryphon's common stock. Cheniere and Warburg have also agreed, under certain
circumstances, to contribute to Gryphon their respective shares of an additional
$75,000,000 investment. The Gryphon Transaction was consummated on October 11,
2000. See --Investment in Gryphon Exploration Company.
Offshore Texas Project Area. Between June 2000 and October 2000, Cheniere
acquired licenses to approximately 6,800 miles of seismic data primarily in the
shallow waters offshore Texas and also in the West Cameron area in the Gulf of
Mexico (the Offshore Texas Project Area) in separate transactions with Seitel
Data Ltd., a division of Seitel Inc., and JEBCO Seismic, L.P. Cheniere has
committed to reprocess all of the data from the Offshore Texas Project Area at a
cost of approximately $8,500,000, payable in installments beginning in October
2000 and continuing through the final delivery of reprocessed data, which is
expected to occur by December 2001. See --Exploration Programs.
Cheniere's existing data set covering the Cameron Project and the reprocessed
data set covering the Offshore Texas Project Area, as it is delivered, provide
the Company the framework with which to identify potential drilling prospects
which may then be acquired through leasing at the area-wide federal and state
lease sales, through farm-ins (agreements whereby a third party owner of lease
interests grants to the Company the right to earn an assignment of an interest
in the lease, typically by drilling one or more wells), and through
participation in industry prospects. Cheniere has added exploration staff and
infrastructure and plans to engage an exploration partner with the intent of
commencing exploration drilling of the Offshore Texas Project Area during
2001.
As a part of its plans to add exploration staff, in December 2000, Cheniere
entered into an agreement with Aurora Exploration, LLC (Aurora) to assist
Cheniere in the interpretation of the Company's seismic data sets and in the
Company's prospect generation activities. The initial term of the agreement is
through March 2001, but it is anticipated that the agreement will be extended
for an additional two years. Aurora, based in Lafayette, LA, will focus its
efforts on the Mustang Island, Matagorda and West Cameron areas of the Gulf of
Mexico shelf, using a portion of Cheniere's recently licensed seismic data from
the Offshore Texas Project Area.
BUSINESS STRATEGY
The Company's objective is to expand the net value of its assets by building an
oil and gas reserve base in a cost-efficient manner. Cheniere's exploration
program combines the use of regional seismic data in shallow water areas of the
Gulf of Mexico, advanced analytical technologies, a methodology that integrates
geoscience and engineering disciplines, and a core of experienced staff.
Seismic Data
Cheniere has acquired two significant seismic database assets: 1) a 228
square-mile proprietary seismic program covering the transition zone in Cameron
Parish (the Cameron Project described above), and 2) a 6,800 square-mile seismic
database comprising several seismic surveys in the shallow waters offshore Texas
(the Offshore Texas Project Area described above). The offshore Texas database
has been available previously to the industry and was processed using a
technique called dip move out (DMO). Cheniere has acquired the DMO data and is
underwriting the reprocessing of the data utilizing another technology known as
prestack time migration (PSTM). Both DMO and PSTM are processing techniques
which improve seismic data quality to more accurately image subsurface features.
Of the two techniques, PSTM is more advanced and technically accurate. The
regional PSTM data is the technology tool which management believes gives
Cheniere a competitive advantage and is being processed at the rate of
approximately 600-800 square-miles (70-80 blocks) per month.
Analysis
Cheniere has built a prospect generation infrastructure capable of detailed
analyses of large volumes of seismic, geological, and engineering data. At the
center of the analytical capabilities is a UNIX workstation network, which
allows large databases to be shared by the technical staff. Geological and
geophysical interpretation, modeling, and mapping software packages are
available on the network for use by each of the geoscientists to generate and
refine drilling opportunities. A thorough analysis of the various technical
factors, utilizing some of these advanced evaluation capabilities, is essential
to accurately quantify reserve potential and risks.
Methodology
Cheniere employs a rigorous methodology which includes: 1) the detailed analyses
of existing fields to identify geological and geophysical attributes for use as
analogs, 2) regional trend mapping to extend prolific plays into under-explored
areas, 3) the use of workstation interpretation techniques to rapidly identify
prospects with attributes similar to those identified in the analog fields, 4)
the integration of seismic interpretation, well control, structure,
stratigraphy, timing, sourcing factors, and production data to quantify prospect
potential, and 5) the integration of the above sciences with experience and
conservative economic evaluation to focus the exploration program on highly
commercial projects. By conducting a thorough analysis of the data and strict
adherence to the methodology, Cheniere believes it can reduce the risk of dry
holes and achieve significant growth, while maintaining a competitive
4
cost of finding and development.
Experience
Cheniere has built a technical and management team that is experienced in the
Gulf of Mexico and in various technical specialties required for its exploration
program. The technical staff averages 20 years of experience exploring for oil
and gas in the Gulf Coast, and each individual has a proven track record of
discoveries. The Company believes this experienced team allows it to be very
productive in the generation and acquisition of prospects and drilling of
exploratory wells.
EXPLORATION PROGRAMS
The Company's current oil and gas exploration and development activities are
focused on two areas: (i) the Cameron Project, which covers an area extending
roughly three to five miles on either side of the westernmost 28 miles of
Louisiana coastline; and (ii) the Offshore Texas Project Area, which covers
approximately 6,800 square miles in the shallow waters offshore Texas.
Substantial infrastructure along the Gulf Coast and in the shallow Gulf of
Mexico should permit Cheniere to lower its development costs compared to those
in other geographic regions and facilitate timely development of oil and gas
discoveries. The Company's officers and technical staff have extensive
experience both onshore and offshore in the Gulf Coast and believe the Company
is well-positioned to evaluate, explore and develop properties in these areas.
Proprietary Seismic Exploration Program in Cameron Project
Under the terms of an exploration agreement with an industry partner covering
the Cameron Project, Cheniere paid for certain seismic costs and earned a 50%
interest in seismic data covering the Cameron Project. Neither party to the
exploration agreement may sell or license the acquired seismic data without the
other party's approval.
In addition to ownership of the seismic data, under the exploration agreement,
Cheniere has the right to acquire a 50% working interest in prospects generated
by its partner within the Cameron Project. In addition to its right to
participate in prospects generated by its partner, Cheniere has elected to
reprocess and interpret the seismic data itself in order to generate its own
prospects. Under the exploration agreement, leases acquired by either Cheniere
or its partner within the Cameron Project may be subject to an area of mutual
interest, under which the other party would have the right to acquire a 50%
interest in acquired leases. The area of mutual interest will expire May 15,
2001.
Seismic Exploration Program in Offshore Texas Project Area
In June 2000, Cheniere acquired a license to approximately 1,900 square miles of
seismic data from Seitel Data Ltd., a division of Seitel Inc. In October 2000,
Cheniere exercised its option to expand the agreement with Seitel Data Ltd. to
cover an additional 1,900 square miles of seismic data. Together, the licenses
acquired from Seitel represent coverage over 433 Outer Continental Shelf blocks
in the shallow waters offshore Texas and Louisiana in the Gulf of Mexico.
In October 2000, Cheniere negotiated a Master Data Users Agreement with the
Houston-based firm, JEBCO Seismic L.P., to acquire 3,000 square miles (333
blocks) of seismic data in both state and federal waters offshore Texas,
bringing Cheniere's total data set in the shallow waters offshore Texas and
Louisiana to approximately 6,800 square miles of seismic coverage. Cheniere has
added exploration staff and infrastructure and plans to engage an exploration
partner with the intent of commencing exploration drilling of the Offshore Texas
Project Area during 2001. Cheniere has committed to reprocess all of the data
from the Offshore Texas Project Area at a cost of approximately $8,500,000,
payable in installments beginning in October 2000 and continuing through the
final delivery of reprocessed data, which is expected to occur in October 2001.
Drilling Activities
In 1999, the Company drilled and completed two discovery wells located in
adjacent fault blocks on West Cameron Block 49 in Louisiana state waters: the
Redfish well and the Stingray well. The wells were tied into a common platform
and began production during September 1999. During 2000, the wells produced 1.5
bcfe. Both wells are located in shallow waters of approximately 25 feet and were
drilled into the Lower Miocene formation from 9,000 to 11,000 feet. Cheniere
owns a 30% working interest in the Redfish well and a 45% working interest in
the Stingray well.
During 2000, the Company commenced drilling an additional exploration well on
West Cameron Block 49, known as the Shark well. In connection with the Gryphon
Transaction, Cheniere assigned its interest in the Shark well, which was then
being drilled, to Gryphon. Gryphon subsequently completed the well in February
2001. Production of natural gas from the Shark well is handled through a common
platform which, since September 1999, has also handled production from the
Company's Stingray and Redfish
5
wells. Further drilling in the Cameron Project is scheduled for 2001 on leased
prospects, and leasing on additional prospects is ongoing.
Investment in Gryphon Exploration Company
Cheniere has a 36.8% interest in Gryphon, after giving effect to the conversion
of all shares of Gryphon's convertible preferred stock to shares of Gryphon
common stock, but does not participate in the day-to-day management of Gryphon,
does not exercise control over Gryphon, and cannot effect a change in the
management of Gryphon.
In the Gryphon Transaction, the Company contributed the license to 8,800 square
miles of seismic data that it had originally licensed from Fairfield Industries.
The data covered more than 1,100 outer continental shelf blocks in the shallow
waters of the Gulf of Mexico (the Offshore Louisiana Area). Cheniere also
assigned its rights in its Joint Exploration Agreement with Samson. Under that
agreement, Samson has the option to participate as a 50% working interest owner
in any drilling prospect generated or acquired by Cheniere in a designated area
of mutual interest coincident with the Offshore Louisiana Area within the Gulf
of Mexico.
The Company also assigned to Gryphon its rights in certain leases, including the
Shark Prospect on West Cameron Block 49. Gryphon has initiated production from
the Shark well in February 2001, and by month-end, the well was flowing at a
rate of 11 mmcf/day. Gryphon has a 29% working interest in the Shark well.
Gryphon has developed an inventory of more than 40 leads and prospects. As of
March 26, 2001, Gryphon had two wells for which drilling was in progress.
Depending on rig availability, Gryphon anticipates drilling up to twelve
exploration wells during 2001. Gryphon is also engaged in acquiring drilling
prospects through leasing at area-wide federal and state lease sales and through
farm-ins of leased acreage.
PRODUCTION AND SALES
The following table presents certain information with respect to oil and natural
gas production attributable to the Company, average sales prices received and
average production costs during 2000 and 1999. The Company commenced oil and gas
production on September 9, 1999.
Year Ended Year Ended
December 31, 2000 December 31, 1999
--------------------------- ---------------------------
Production:
Oil (bbls) 3,703 2,975
Gas (mmcf) 1,459,897 633,432
Gas equivalents (mmcfe) 1,482,117 651,282
Average sales prices:
Oil (per barrel) $ 29.78 $ 23.18
Gas (per mcf) $ 3.79 $ 2.59
Selected data per mcfe:
Average sales price $ 3.59 $ 2.48
Production costs $ 0.26 $ 0.20
Oil and gas depreciation, depletion and amortization $ 2.04 $ 1.84
6
ACREAGE AND WELLS
The following table sets forth certain information with respect to the Company's
developed and undeveloped leased acreage as of December 31, 2000.
DEVELOPED ACRES UNDEVELOPED ACRES (1)
----------------------------------- -----------------------------------------
GROSS NET GROSS NET
-------------- ---------------- ---------------- --------------------
Louisiana 1,366 513 1,466 1,352
Texas -- -- -- --
-------------- ---------------- ---------------- --------------------
Total 1,366 513 1,466 1,352
============== ================ ================ ====================
(1) The Company has no leases which expire in 2001.
At December 31, 2000, the Company had working interests in 2 gross (0.75 net)
producing gas wells.
DRILLING ACTIVITIES
All of Cheniere's drilling activities are conducted through arrangements with
independent contractors. Cheniere owns no drilling equipment. Certain
information with regard to the Company's drilling activities, during the years
ended December 31, 2000 and December 31, 1999, is set forth below:
YEAR ENDED YEAR ENDED
DECEMBER 31, 2000 DECEMBER 31, 1999
------------------------------------ ------------------------------------
NET WORKING NET WORKING
GROSS INTEREST GROSS INTEREST
--------------- --------------- --------------- ---------------
Development wells -- -- -- --
--------------- --------------- --------------- ---------------
Exploratory wells:
Oil -- -- -- --
Gas -- -- 2 0.8
Nonproductive -- -- 4 2.5
--------------- --------------- --------------- ---------------
Total -- -- 6 3.3
--------------- --------------- --------------- ---------------
Total wells -- -- 6 3.3
=============== =============== =============== ===============
Cheniere drilled no wells prior to 1999. All of the Company's wells are located
in the United States. Although the Company commenced drilling the Shark well
during 2000, the Company assigned its interest in the Shark well to Gryphon, its
unconsolidated affiliate, in connection with the Gryphon Transaction in October
2000. At December 31, 2000, the Company was not participating in the drilling of
any wells.
OIL AND GAS RESERVES
All information herein regarding estimates of Cheniere's proved reserves,
related future net revenues and PV-10 is taken from reports generated by Ryder
Scott Company, the Company's independent petroleum engineers, in accordance with
the rules and regulations of the SEC. The independent engineers' estimates were
based upon a review of production histories and other geologic, economic,
ownership and engineering data provided by the Company.
7
DECEMBER 31, 2000
--------------------------------------------------------------------------
PROVED RESERVES
--------------------------------------------------------------------------
OIL GAS
(BBLS) (MCF) MCFE PV-10 (1)
-------------- -------------- -------------- ---------------
West Cameron Block 49 19,874 4,568,000 4,687,244 $ 20,618,002
-------------- -------------- -------------- ---------------
Proved Reserves - Consolidated 19,874 4,568,000 4,687,244 $ 20,618,002
============== ============== ============== ===============
Proved Reserves - Total (2) 22,514 6,242,000 6,377,084 $ 29,756,922
============== ============== ============== ===============
Proved Developed Reserves -
Consolidated 16,913 3,982,000 4,083,478 $ 17,080,027
============== ============== ============== ===============
Proved Developed Reserves - Total (2) 19,553 5,656,000 5,773,318 $ 26,218,947
============== ============== ============== ===============
(1) The PV-10 amount (present value of estimated future net revenues discounted
at 10%) is calculated using year-end prices of $29.72 per barrel of oil and
$10.71 per mcf of gas.
(2) Includes Cheniere's proportional share, based on its 100% common stock
ownership, of the proved reserves, proved developed reserves and PV-10 value of
Gryphon ( 2,640 barrels of oil, 1,674,000 mcf of gas and PV-10 of $9,138,920).
Such proportional share of Gryphon reserves and PV-10 value is based upon
Cheniere's ownership of 100% of Gryphon's common stock and will be reduced to
36.8% upon the conversion of Gryphon's preferred shares. See --General
Development of Business.
There are numerous uncertainties inherent in estimating quantities of proved
reserves and in projecting future rates of production and future amounts and
timing of development expenditures, including many factors beyond the control of
the Company. Reserve engineering is a subjective process of estimating
underground accumulations of crude oil and natural gas that cannot be measured
in an exact manner, and the accuracy of any reserve estimate is a function of
the quality of available data and of engineering and geological interpretation
and judgment. Estimates of proved undeveloped reserves are inherently less
certain than estimates of proved developed reserves. The quantities of oil and
gas that are ultimately recovered, production and operating costs, the amount
and timing of future development expenditures, geologic success and future oil
and gas sales prices may all differ from those assumed in these estimates. In
addition, the Company's reserves may be subject to downward or upward revision
based upon production history, purchases or sales of properties, results of
future development, prevailing oil and gas prices and other factors. Therefore,
the present value shown above should not be construed as the current market
value of the estimated oil and gas reserves attributable to the Company's
properties.
In accordance with SEC guidelines, the independent engineers' estimates of
future net revenues from the Company's proved reserves and the present value
thereof are made using oil and gas sales prices in effect as of the dates of
such estimates and are held constant throughout the life of the properties
except where such guidelines permit alternate treatment, including, in the case
of gas contracts, the use of fixed and determinable contractual price
escalations. The Company may receive amounts different than the independent
engineers' estimates for a number of reasons, including changes in prices. See
Supplemental Information to Consolidated Financial Statements. Estimates of the
Company's proved oil and gas reserves were not filed with or included in reports
to any other federal authority or agency other than the SEC during the fiscal
year ended December 31, 2000.
COMPETITION AND MARKETS
Competition in the industry is intense, particularly with respect to the
acquisition of producing properties and proved undeveloped acreage. The Company
competes with the major oil companies and other independent producers of varying
sizes, all of which are engaged in the exploration, development and acquisition
of producing and non-producing properties. Many of the Company's competitors
have financial resources and exploration and development budgets that are
substantially greater than those of the Company, which may adversely affect the
Company's ability to compete.
The Company anticipates selling a portion of its interest in certain prospects
as a means of funding its participation in the development of these properties.
The Company anticipates that competition will arise from other companies seeking
drilling funds from potential working interest partners. There can be no
assurance that the Company will be successful in securing funds in this manner.
The availability of a ready market for and the price of any hydrocarbons
produced by the Company will depend on many factors beyond the control of the
Company, including the extent of domestic production and imports of foreign oil,
the marketing of competitive fuels, the proximity and capacity of natural gas
pipelines, the availability of transportation and other market facilities, the
8
demand for hydrocarbons, the political conditions in international oil-producing
regions, the effect of federal and state regulation of allowable rates of
production, taxation, the conduct of drilling operations, and federal regulation
of natural gas. In the past, as a result of excess deliverability of natural
gas, many pipeline companies curtailed the amount of natural gas taken from
producing wells, shut in some producing wells, significantly reduced gas taken
under existing contracts, refused to make payments under applicable take-or- pay
provisions, and have not contracted for gas available from some newly completed
wells. The Company can give no assurance that such conditions will not arise
again.
In addition, the restructuring of the natural gas pipeline industry has
eliminated the gas purchasing activity of traditional interstate gas
transmission pipeline buyers. Producers of natural gas, therefore, have been
required to develop new markets among gas marketing companies, end-users of
natural gas, and local distribution companies. All of these factors, together
with economic factors in the marketing area, generally may affect the supply
and/or demand for oil and gas and thus the prices available for sales of oil and
gas.
GOVERNMENT REGULATION
The Company's oil and gas exploration, production, and related operations are
subject to federal and state statutes and extensive rules and regulations
promulgated by federal and state agencies. Failure to comply with such laws can
result in substantial penalties. The regulatory burden on the oil and gas
industry increases the Company's cost of doing business and affects its
profitability. Because such laws are frequently amended or reinterpreted, the
Company is unable to predict the future cost or impact of complying with them.
Production
In most, if not all, areas in which the Company conducts activities, statutes
concerning the production of oil and natural gas authorize administrative
agencies to adopt rules which, among others matters, (i) regulate the operation
of, and production from, both oil and gas wells, (ii) determine the reasonable
market demand for oil and gas, and (iii) establish allowable rates of
production. Such regulation may restrict the rate at which the Company's wells
may produce oil or gas, with the result that the amount or timing of the
Company's revenues could be adversely affected.
MMS Regulation
The Company may conduct certain activities on federal oil and gas leases which
the Minerals Management Service (MMS) administers. The MMS grants leases through
competitive bidding. These leases contain relatively standardized terms and
require compliance with detailed MMS regulations and orders pursuant to The
Outer Continental Shelf Lands Act (OCSLA) (which regulations and orders are
subject to change by the MMS). For offshore operations, lessees must obtain MMS
approval for exploration plans and development and production plans prior to the
commencement of such operations. In addition to permits which may be required
from other agencies (such as the Coast Guard, the Army Corps of Engineers and
the Environmental Protection Agency), lessees must obtain a permit from the MMS
prior to the commencement of drilling. The MMS has adopted regulations requiring
offshore production facilities located on the Outer Continental Shelf (OCS) to
meet stringent engineering and construction specifications. The MMS also has
regulations restricting the flaring or venting of natural gas, and has amended
such regulations to prohibit the flaring of liquid hydrocarbons and oil without
prior authorization except under certain limited circumstances. Also, the MMS
has promulgated other regulations governing the plugging and abandonment of
wells located offshore and the removal of all production facilities. To cover
the various obligations of lessees on the OCS, the MMS generally requires that
lessees post substantial bonds or other acceptable assurances that such
obligations will be met. The cost of such bonds or other surety can be
substantial and there is no assurance that the Company will be able to obtain
such bonds or other surety in all cases.
In March 2000, the MMS amended its regulations governing the calculation of
royalties and the valuation of crude oil produced from federal leases. This rule
modifies the valuation procedures for both arm's length and non-arm's length
crude oil transactions to decrease reliance on oil posted prices and assign a
value to crude oil that better reflects its market value. The Company cannot
predict how it will be affected by this regulation.
In April 1997, after two years of study, the MMS withdrew proposed changes to
the way it values natural gas for royalty payments and requested comment on two
alternative options for natural gas valuation. The changes as originally
proposed would have established an alternative market-based method to calculate
royalties on certain natural gas sold to affiliates or pursuant to non-arm's
length sales contracts. Informal discussions among the MMS and industry
officials are continuing, although it is uncertain whether, and what, changes
may be proposed regarding gas royalty valuation.
Bonding and Financial Responsibility Requirements
The Company is required to obtain bonding, or otherwise demonstrate financial
responsibility, at varying levels by governmental agencies in connection with
obtaining state or federal leases or acting as an owner or operator on such
leases or of exploration and production related facilities. These bonds may
cover such obligations as plugging and abandonment of unproductive wells,
removal
9
and closure of related exploration, production facilities, and pollution
liabilities. The costs of such bonding and financial responsibility requirements
can be substantial, and there can be no assurance that the Company will be able
to obtain such bonds and/or otherwise demonstrate financial responsibility in
all cases.
Natural Gas Marketing and Transportation
The Federal Energy Regulatory Commission (FERC) regulates the transportation and
sale for resale of natural gas in interstate commerce pursuant to the Natural
Gas Act of 1938 (NGA) and the Natural Gas Policy Act of 1978 (the NGPA). In the
past, the federal government has regulated the prices at which natural gas could
be sold. Deregulation of wellhead sales of natural gas began with the enactment
of the NGPA in 1978. In 1989, Congress enacted the Natural Gas Wellhead
Decontrol Act (the Decontrol Act) which removed all NGA and NGPA price and
nonprice controls affecting wellhead sales of natural gas effective January 1,
1993. While sales by producers of natural gas can currently be made at
uncontrolled market prices, Congress could reenact price controls in the future.
Commencing in April 1992, the FERC issued its Order No. 636 and related
clarifying orders (Order No. 636), which, among other things, restructured the
interstate natural gas industry and required interstate pipelines to provide
transportation services separate, or unbundled, from the pipelines' sales of
natural gas. Order No. 636 and certain related proceedings have been the subject
of a number of judicial appeals and orders on remand by the FERC. Order No. 636
has largely been upheld on appeal. The Company cannot predict when these
remaining appeals will be completed or their impact on the Company. The FERC
continues to address Order 636-related issues (including capacity brokering,
alternative and negotiated ratemaking and transportation policy matters) in a
number of pending proceedings. It is unclear what impact, if any, increased
competition within the natural gas industry under Order Nos. 636, et al., will
have on the Company's activities. Although Order No. 636 could provide the
Company with additional market access and more fairly applied transportation
service rates, Order No. 636 could also subject the Company to more restrictive
pipeline imbalance tolerances and greater penalties for violations of these
tolerances.
The FERC has announced its intention to re-examine certain of its
transportation-related policies, including the appropriate manner in which
interstate pipelines release transportation capacity under Order No. 636, and
the use of market-based rates for interstate gas transmission. While any
resulting FERC action would affect the Company only indirectly, the FERC's
current rules and policy statements may have the effect of enhancing competition
in natural gas markets by, among other things, encouraging non-producer natural
gas marketers to engage in certain purchase and sale transactions. The Company
cannot predict what action the FERC will take on these matters, nor can it
accurately predict whether the FERC's actions will achieve the goal of
increasing competition in markets in which the Company's natural gas is sold.
However, the Company does not believe that it will be treated materially
differently than other natural gas producers and marketers with which it
competes.
OCSLA requires that all pipelines operating on or across the OCS provide open-
access, non-discriminatory service. Although the FERC has opted not to impose
the regulations of Order No. 509, in which the FERC implemented OCSLA, on
gatherers and other non-jurisdictional entities, the FERC has retained the
authority to exercise jurisdiction over those entities if necessary to permit
non-discriminatory access to service on OCS. In this regard, the FERC issued a
Statement of Policy (Policy Statement) regarding the application of its
jurisdiction under the NGA and OCSLA over natural gas facilities and service on
OCS. In the Policy Statement, the FERC concluded that facilities located in
water depths of 200 meters or more shall be presumed to have a primary purpose
of gathering up to the point of interconnection with the interstate pipeline
grid. The FERC has determined that gathering facilities are outside of its
jurisdiction, and thus, it will no longer regulate the rates and services of
such OCS facilities under the NGA. While it is not possible to determine what
the actual impact of this new policy will be, it is possible that the Company
could experience an increase in transportation costs associated with its OCS
natural gas production and, possibly, reduced access to OCS transmission
capacity.
The FERC has also issued numerous orders approving the sale and abandonment of
natural gas gathering facilities previously owned by interstate pipelines and
has acknowledged that if the FERC does not have jurisdiction over services
provided thereon, then such facilities and services may be subject to regulation
by state authorities in accordance with state law. A number of states have
either enacted new laws or are considering the inadequacy of existing laws
affecting gathering rates and/or services. In addition, the FERC's approval of
transfers of previously regulated gathering systems to independent or pipeline-
affiliated gathering companies that are not subject to FERC regulation may
affect both the costs and the nature of gathering services that will be
available to interested producers or shippers in the future. The effects, if
any, of state and federal gathering policies on the Company's operations are
uncertain.
Oil Sales and Transportation Rates
Sales of crude oil, condensate, and gas liquids by the Company are not currently
regulated under federal or state law and are made at market prices. The FERC
regulates the transportation of oil in interstate commerce pursuant to the
Interstate Commerce Act. However, the price a Company receives from the sale of
these products is affected by the cost of transporting the products to market.
Effective as of January 1, 1995, the FERC implemented regulations establishing
an indexing system for transportation rates for oil pipelines, which would
generally index such rates to inflation, subject to certain conditions and
limitations. Over time, these
10
regulations could increase the cost of transporting crude oil, liquids, and
condensate by pipeline. The Company is not able to predict with certainty what
effect, if any, these regulations will have on it; but other factors being
equal, these regulations may tend to increase transportation costs or reduce
wellhead prices for such commodities.
Operating Hazards and Environmental Matters
The oil and gas business involves a variety of operating risks, including the
risk of fire, explosions, blow-outs, pipe failure, casing collapse, abnormally
pressured formations and environmental hazards such as oil spills, natural gas
leaks, ruptures and discharge of toxic gases, the occurrence of any of which
could result in substantial losses to the Company due to injury or loss of life,
severe damage to or destruction of property, natural resources and equipment,
pollution or other environmental damage, clean-up responsibilities, regulatory
investigation and penalties and suspension of operations. Such hazards may
hinder or delay drilling, development and on-line production operations.
Extensive federal, state and local laws and regulations applicable to oil and
gas operations regulate the discharge of substances into the environment or
otherwise relate to the protection of the environment. These laws and
regulations may require the acquisition of a permit before drilling commences,
restrict or prohibit the types, quantities and concentration of substances that
can be released into the environment or wastes that can be disposed of in
connection with drilling and production activities, prohibit drilling activities
on certain lands lying within wetlands or other protected areas and impose
substantial liabilities for pollution or releases of hazardous substances
resulting from drilling and production operations. Failure to comply with these
laws and regulations may also result in civil and criminal fines and penalties.
Moreover, state and federal environmental laws and regulations may become more
stringent.
The Comprehensive Environmental Response, Compensation and Liability Act
(CERCLA), also known as the Superfund law, imposes liability, without regard to
fault or the original conduct, on certain classes of persons who are considered
to be responsible for the release of a hazardous substance into the environment.
These persons include the owner or operator of the disposal site or sites where
the release occurred and companies that disposed or arranged for the disposal of
the hazardous substances. Under CERCLA, such persons may be subject to joint and
several liability for the costs of cleaning up the hazardous substances that
have been released into the environment, for damages to natural resources and
for the costs of certain health studies, and it is not uncommon for neighboring
landowners and other third parties to file claims for personal injury and
property damage allegedly caused by the release of hazardous substances.
The Company's operations may be subject to the Clean Air Act (CAA) and
comparable state and local requirements. Amendments to the CAA were adopted in
1990 and contain provisions that may result in the gradual imposition of certain
pollution control requirements with respect to air emissions from the operations
of the Company. The EPA and states have been developing regulations to implement
these requirements. The Company may be required to incur certain capital
expenditures in the next several years for air pollution control equipment in
connection with maintaining or obtaining permits and approvals addressing other
air emission-related issues. The Company does not believe, however, that its
operations will be materially adversely affected by any such requirements.
In addition, the U.S. Oil Pollution Act (OPA) requires owners and operators of
facilities that could be the source of an oil spill into waters of the United
States (a term defined to include rivers, creeks, wetlands, and coastal waters)
to adopt and implement plans and procedures to prevent any spill of oil into any
waters of the United States. OPA also requires affected facility owners and
operators to demonstrate that they have at least $35 million in financial
resources to pay for the costs of cleaning up an oil spill and compensating any
parties damaged by an oil spill. Such financial assurances may be increased to
as much as $150 million if a formal assessment indicates such an increase is
warranted.
Operations of the Company are also subject to the federal Clean Water Act (CWA)
and analogous state laws. In accordance with the CWA, the state of Louisiana has
issued regulations prohibiting discharges of produced water in state coastal
waters, effective July 1, 1997. Producers may be required to incur certain
capital expenditures in the next several years in order to comply with the
prohibition against the discharge of produced waters into Louisiana coastal
waters or increase operating expenses in connection with offshore operations in
Louisiana coastal waters. Pursuant to other requirements of the CWA, the EPA has
adopted regulations concerning discharges of 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. The Company believes that
it will be able to obtain, or be included under, such storm water discharge
permits, where necessary.
In addition, the disposal of wastes containing naturally occurring radioactive
material, which are commonly generated during oil and gas production, is
regulated under state law. Typically, wastes containing naturally occurring
radioactive material can be managed on-site or disposed of at facilities
licensed to receive such waste at costs that are not expected to be material.
11
OPERATIONAL RISKS AND INSURANCE
The Company anticipates that any wells established by it will be drilled by
proven industry contractors. Based on financial considerations, the Company may
choose to utilize turnkey drilling contracts that limit its financial and legal
exposure. Under a turnkey drilling contract, a negotiated price is agreed upon
and the money is placed in escrow. The drilling contractor then assumes all of
the risk and expense, including any cost overruns, of drilling a well to
contract depth and completing any agreed upon evaluation of the wellbore. Upon
performance of all these items, the escrowed money is released to the
contractor. Circumstances may arise where the Company is unable to secure a
turnkey contract on satisfactory terms. In this case, the Company may decide to
drill, or cause to be drilled, the applicable test well(s) on either a footage
or day- rate basis. Under a footage drilling contract, the operator pays to the
drilling contractor an agreed sum per foot drilled. Under a day-rate drilling
contract, the operator pays an agreed sum for each day of drilling required to
reach contract depth. All risk and expense, including cost overruns, of drilling
a well to total depths lies with the operator in both footage and day-rate
contracts. The drilling of such test wells will be subject to the usual drilling
hazards such as cratering, explosions, uncontrollable flows of oil, gas or well
fluids, fires, pollution, and other environmental risks. The Company's
activities are also subject to perils specific to marine operations, such as
capsizing, collision, and damage or loss from severe weather. These hazards can
cause personal injury and loss of life, severe damage to and destruction of
property and equipment, pollution or environmental damage, and suspension of
operations. In accordance with customary industry practices, the Company intends
to maintain insurance against some, but not all, of such risks, and some, but
not all, of such losses. The occurrence of a significant event not fully insured
or indemnified against could materially and adversely affect the Company's
financial condition and operations. Moreover, no assurance can be given that the
Company will be able to maintain adequate insurance in the future at rates
considered reasonable by the Company.
EMPLOYEES
The Company had 12 full-time employees as of March 30, 2001.
FORWARD-LOOKING STATEMENTS AND RISK FACTORS
This annual report contains certain statements that may be deemed forward-
looking statements within the meaning of Section 27A of the Securities Act of
1933, as amended (Securities Act), and Section 21E of the United Stated
Securities Exchange Act of 1934, as amended (Exchange Act). Readers of this
annual report are cautioned that such forward-looking statements are not
guarantees of future performance and that actual results, developments and
business decisions may differ from those envisaged by such forward-looking
statements.
All statements, other than statements of historical facts so included in this
annual report that address activities, events or developments that the Company
intends, expects, projects, believes, or anticipates will or may occur in the
future, including, without limitation: statements regarding the Company's
business strategy, plans and objectives; statements expressing beliefs and
expectations regarding the ability of the Company to successfully raise the
additional capital necessary to meet its obligations, the ability of the Company
to secure the leases necessary to facilitate anticipated drilling activities and
the ability of the Company to attract additional working interest owners to
participate in the exploration and development of oil and gas reserves, and
statements about non-historical Year 2000 information, are forward-looking
statements within the meaning of the Act. These forward-looking statements are,
and will be, based on management's then-current views and assumptions regarding
future events.
The following are some of the important factors that could affect the Company's
financial performance or could cause actual results to differ materially from
estimates contained in the Company's forward-looking statements. The important
factors are not exclusive.
12
THE COMPANY HAS A LIMITED OPERATING HISTORY DURING WHICH IT HAS INCURRED LOSSES,
AND IT MAY CONTINUE TO INCUR LOSSES.
The Company has a limited operating history with respect to its oil and gas
exploration activities, which were commenced in April 1996. From the Company's
inception until the quarter ended June 30, 2000 and subsequently, it has
incurred losses and may continue to incur losses, depending on whether it
generates sufficient revenue from producing reserves acquired either through
acquisitions or drilling activities.
THE COMPANY HAS LIMITED CURRENT OIL AND GAS PRODUCTION AND LIMITED PROVED
RESERVES, WHICH MEANS THAT ITS SUCCESS IS HIGHLY DEPENDENT ON THE SUCCESS OF ITS
EXPLORATION PROGRAM.
Cheniere established its initial oil and gas production in September 1999.
Through its drilling in 1999, the Company established proved reserves, which
means that it has identified oil and gas reserves that geological and
engineering data demonstrate with reasonable certainty to be recoverable in
future years from known reservoirs under existing economic and operating
conditions. The focus of Cheniere's business is exploratory drilling. Because
almost all of the Company's assets are represented by investments to date in its
exploration program, and the Company anticipates investing additional amounts in
the program, the Company is highly dependent on the success of its exploration
program.
THE COMPANY MAY NEED ADDITIONAL FINANCING AND MAY NOT BE ABLE TO OBTAIN IT ON
TERMS THAT ARE ACCEPTABLE TO THE COMPANY, WHICH COULD HARM ITS ABILITY TO
CONDUCT BUSINESS.
Cheniere presently has limited operating revenues. As of December 31, 2000,
Cheniere had $2,838,800 of current assets and working capital of $1,234,390.
Because of its low level of current assets, the Company may need additional
capital for a number of purposes, and if the Company were unable to obtain
additional financing it could significantly harm Cheniere's ability to conduct
its business, including its ability to take advantage of opportunities that come
from its exploration program. Cheniere's needs for additional financing include
the following:
. Additional capital will be required to pay for Cheniere's share of costs
relating to the drilling of prospects and development of those that are
successful, to exercise lease options, and to acquire additional oil and gas
leases. The total amount of the Company's capital needs will be determined in
part by the number of prospects generated within its exploration program and by
the working interest that the Company retains in those prospects.
. The Company will need funds for the payment of approximately $8,000,000
related to future deliveries of reprocessed seismic data through December 2001.
. The Company may need capital to fund its pro-rata share of the capital calls
by Gryphon that are approved by Gryphon's Board of Directors. The Company's
share of such future capital calls could total up to $27,600,000. If the Company
elects not to fund its pro-rata portion of such capital calls, and Warburg funds
its portion, as they would be entitled, the Company will suffer dilution of its
holdings in Gryphon. If the Company subscribes to its pro-rata portion of such
capital calls but fails to fund, it would lose its ability to subscribe to any
future capital calls and would suffer dilution of its holdings in Gryphon. It is
anticipated that Gryphon will make cash calls for additional funds during 2001.
. The Company will need funds for the payment of a transfer fee related to the
assignment to Gryphon of its seismic license over the Offshore Louisiana Project
Area. Cheniere is obligated to pay a transfer fee of up to $2,500,000, in ten
installments of $250,000, which would become payable after one month of
production from each of ten separate successful wells completed by Gryphon
within the data set.
. Should the Company choose to make an acquisition of producing oil and gas
properties, it is likely that such an acquisition would require that some
portion of the purchase price be paid in cash, and thus would create the need
for additional capital.
Additional capital could be obtained from a combination of funding sources.
These potential funding sources include:
. cash flow from operating activities,
. borrowings from financial institutions,
13
. debt offerings, which would increase the Company's leverage and add to its
need for cash to service such debt,
. additional offerings of the Company's equity securities, which would cause
dilution of its common stock,
. sales of portions of its working interest in the prospects within its
exploration program, which would reduce future revenues from its exploration
program,
. sale to an industry partner of a participation in the Company's exploration
program, including sale of a license to the approximate 6,800 square miles of
seismic data in the Offshore Texas Project Area, which would reduce future
revenues from its exploration program, and
. sale of all or a portion of the Company's producing oil and gas properties,
which would reduce future revenues.
Cheniere's ability to raise additional capital will depend on the results of its
operations and the status of various capital and industry markets at the time
such additional capital is sought. Accordingly, there can be no assurances that
capital will be available to the Company from any source or that, if available,
it will be on terms acceptable to the Company.
BECAUSE OF THE COMPANY'S LACK OF DIVERSIFICATION, FACTORS HARMING THE OIL AND
GAS INDUSTRY IN GENERAL, INCLUDING DOWNTURNS IN PRICES FOR OIL AND GAS, WOULD BE
ESPECIALLY HARMFUL TO IT.
As an independent energy company, Cheniere's revenues and profits will be
substantially dependent on the oil and gas industry in general and the
prevailing prices for oil and gas in particular. Circumstances that harm the oil
and gas industry in general will have an especially harmful effect on Cheniere.
Oil and gas prices have been and are likely to continue to be volatile and
subject to wide fluctuations in response to any of the following factors:
. relatively minor changes in the supply of and demand for oil and gas;
. political conditions in international oil producing regions;
. the extent of domestic production and importation of oil in relevant markets;
. the level of consumer demand;
. weather conditions;
. the competitive position of oil or gas as a source of energy as compared with
other energy sources;
. the refining capacity of oil purchasers; and
. the effect of federal and state regulation on the production, transportation
and sale of oil and gas.
It is likely that adverse changes in the oil market or the regulatory
environment would have an adverse effect on the Company's ability to obtain
capital from lending institutions, industry participants, private or public
investors or other sources.
THE COMPANY EXPERIENCES COMPETITION IN THE OIL AND GAS INDUSTRY, WHICH MAY MAKE
IT DIFFICULT FOR THE COMPANY TO SUCCEED.
The oil and gas industry is highly competitive. If Cheniere is unable to compete
effectively, it will not succeed. A number of factors may give the Company's
competitors advantages over Cheniere. For example, most of the Company's current
and potential competitors have significantly greater financial resources and a
significantly greater number of experienced and trained managerial and technical
personnel than the Company does. There can be no assurance that Cheniere will be
able to compete effectively with such companies. Moreover, the oil and gas
industry competes with other industries in supplying the energy and fuel needs
of industrial, commercial and other consumers. Increased competition causing
over supply and depressed prices could greatly affect Cheniere's operating
revenues.
14
THE COMPANY IS SUBJECT TO SIGNIFICANT OPERATING HAZARDS AND UNINSURED RISKS, ONE
OR MORE OF WHICH MAY CREATE SIGNIFICANT LIABILITIES FOR IT.
The Company's oil and gas operations are subject to all of the risks and hazards
typically associated with the exploration for, and the development and
production of, oil and gas. In accordance with customary industry practices, the
Company intends to maintain insurance against some, but not all, of these risks
and losses. The occurrence of a significant event not fully insured or
indemnified against could seriously harm the Company. Moreover, no assurance can
be given that the Company will be able to maintain adequate insurance in the
future at rates it considers reasonable. Risks in drilling operations include
cratering, explosions, uncontrollable flows of oil, gas or well fluids, fires,
pollution and other environmental risks. The Company's activities are also
subject to perils specific to marine operations, such as capsizing, collision
and damage or loss from severe weather. These hazards can cause personal injury
and loss of life, severe damage to and destruction of property and equipment,
pollution or environmental damage and suspension of operations.
THE COMPANY IS SUBJECT TO SIGNIFICANT EXPLORATION RISKS, INCLUDING THE RISK THAT
IT MAY NOT BE ABLE TO FIND OR PRODUCE ENOUGH OIL AND GAS TO GENERATE ANY
PROFITS.
The Company's exploration activities involve significant risks, including the
risk that it may not be able to find or produce enough oil and gas to generate
any profits. There can be no assurance that the use of technical expertise as
applied to geophysical or geological data will ensure that any well the Company
drills will discover oil or gas. Further, there is no way to know in advance of
drilling and testing whether any prospect will yield oil or gas in sufficient
quantities to make money for the Company. In addition, the Company is highly
dependent on seismic activity and the related application of new technology as a
primary exploration methodology. This methodology, however, requires greater
pre-drilling expenditures than traditional drilling strategies. Even when fully
used and properly interpreted, seismic data can only assist the Company in
identifying subsurface reservoirs and hydrocarbon indicators, and will not allow
the Company to determine conclusively if hydrocarbons will in fact be present
and recoverable. There can be no assurance that the Company's exploration
efforts will be successful.
THE COMPANY MAY NOT BE ABLE TO ACQUIRE THE OIL AND GAS LEASES IT NEEDS TO
SUSTAIN PROFITABLE OPERATIONS.
There can be no assurance that Cheniere will be successful in acquiring farmouts
(agreements whereby the Company, as owner of lease interests, grants to a third
party the right to earn an assignment of an interest in the lease, typically by
drilling one or more wells), seismic permits, lease options, leases or other
rights to explore for or recover oil and gas. Consequently, the area covered by
Cheniere's seismic data that could be explored through drilling could be reduced
if these leases, permits, options and the like are not acquired. The United
States department of the interior and the states of Texas and Louisiana award
oil and gas leases on a competitive bidding basis. Further, non-governmental
owners of the onshore mineral interests within the area covered by the Company's
exploration program are not obligated to lease their mineral rights to the
Company except where the Company has already obtained lease options. Other major
and independent oil and gas companies with financial resources significantly
greater than Cheniere's may bid against Cheniere for the purchase of oil and gas
leases.
IF THE COMPANY IS UNABLE TO OBTAIN SATISFACTORY TURNKEY CONTRACTS, IT MAY HAVE
TO ASSUME ADDITIONAL RISKS AND EXPENSES WHEN DRILLING WELLS.
Cheniere anticipates that any wells drilled in which it has an interest will be
drilled by established industry contractors under turnkey contracts that limit
its financial and legal exposure. Circumstances may arise, however, where a
turnkey contract is not economically beneficial to the Company or is otherwise
unobtainable from proven industry contractors. In such instances, the Company
may decide to drill wells on a day-rate basis, subjecting it to the usual
drilling hazards such as cratering, explosions, uncontrollable flows of oil, gas
or well fluids, fires, pollution and other environmental risks. The Company
would also be liable for any cost overruns attributable to drilling problems
that otherwise would have been covered by a turnkey contract.
Under a turnkey drilling contract, a negotiated price is agreed upon and the
money is placed in escrow. The drilling contractor then assumes all of the risk
and expense, including any cost overruns, of drilling a well to contract depth
and completing any agreed upon evaluation of the wellbore. Upon performance of
all these items, the escrowed money is released to the contractor. On a non-
turnkey basis, all risk and expense, including cost overruns, of drilling a well
to total depths lies with the operator.
15
EXISTING AND FUTURE UNITED STATES GOVERNMENTAL REGULATION, TAXATION AND PRICE
CONTROLS COULD SERIOUSLY HARM THE COMPANY.
Oil and gas production and exploration are subject to comprehensive federal,
state and local laws and regulations controlling the exploration for and
production and sale of oil and gas and the possible effects of such activities
on the environment. Failure to comply with such rules and regulations can result
in substantial penalties and may harm the Company. Present as well as future
legislation and regulations could cause additional expenditures, restrictions
and delays in the Company's business, the extent of which cannot be predicted
and which may require the Company to limit substantially, delay or cease
operations in some circumstances. In most areas where the Company plans to
conduct activities, there are statutory provisions regulating the production of
oil and natural gas which may restrict the rate of production and adversely
affect revenues. The Company plans to acquire oil and gas leases in the Gulf of
Mexico, which will be granted by the federal government and administered by the
U.S. Department of Interior minerals management service. The department strictly
regulates the exploration, development and production of oil and gas reserves in
the Gulf of Mexico. Such regulations could seriously harm the Company's
operations in the Gulf of Mexico. The federal government regulates the
interstate transportation of oil and natural gas, through the Federal Energy and
Regulatory Commission (FERC). The FERC has in the past regulated the prices at
which oil and gas could be sold. Federal reenactment of price controls or
increased regulation of the transport of oil and natural gas could seriously
harm the Company. In addition, the Company's operations are subject to numerous
laws and regulations governing the discharge of oil and hazardous materials into
the environment or otherwise relating to environmental protection, including the
Oil Pollution Act of 1990. These laws and regulations have continually imposed
increasingly strict requirements for water and air pollution control, solid
waste management, and strict financial responsibility and remedial response
obligations relating to oil spill protection. The cost of complying with such
environmental legislation could have a general harmful effect on the Company's
operations.
THERE IS ONLY LIMITED TRADING IN THE COMPANY'S COMMON STOCK, WHICH MAKES ITS
STOCK MORE DIFFICULT TO SELL THAN THE STOCK OF COMPANIES WITH MORE ACTIVE
MARKETS.
Historically, there has been only limited trading in Cheniere's common stock,
which makes its stock more difficult to sell than the stock of companies with
more active markets. For the year 2000, the average trading volume of Cheniere's
common stock was approximately 72,000 shares per day.
THE COMPANY HAS NOT PAID DIVIDENDS AND DOES NOT EXPECT TO DO SO IN THE
FORESEEABLE FUTURE, SO ITS STOCKHOLDERS WILL NOT BE ABLE TO RECEIVE A RETURN ON
THEIR INVESTMENT WITHOUT SELLING THEIR SHARES.
The Company has not paid dividends since its inception and does not expect to in
the foreseeable future, so Cheniere's stockholders will not be able to receive a
return on their investments without selling their shares. The Company presently
anticipates that all earnings, if any, will be retained for development of its
business. Any future dividends will be subject to the discretion of the
Company's board of directors and will depend on, among other things, future
earnings, the Company's operating and financial condition, its capital
requirements and general business conditions.
THE COMPANY'S STOCKHOLDERS COULD EXPERIENCE DILUTION IN THE VALUE OF THEIR
SHARES BECAUSE OF ADDITIONAL ISSUANCES OF SHARES.
Any issuance of common stock by the Company may result in a reduction in the
book value per share or market price per share of its outstanding shares of
common stock and will reduce the proportionate ownership and voting power of
such shares. The Company has 125,000,000 authorized shares of stock, consisting
of 120,000,000 shares of common stock, and 5,000,000 shares of preferred stock.
As of December 31, 2000, approximately 90% of the shares of the common stock
remained unissued. The board of directors has the power to issue any and all of
such shares without shareholder approval. It is likely that the Company will
issue shares of common stock in order to raise capital to sustain operations,
and/or to finance future oil and gas exploration projects. In addition, the
Company has reserved 2,758,621 shares of the common stock for issuance upon the
exercise of outstanding warrants and 1,500,000 shares of the common stock for
issuance upon the exercise of stock options. As of December 31, 2000, there are
884,236 issued and outstanding options to purchase common stock. To the extent
that outstanding warrants and options are exercised, the percentage ownership of
common stock of the Company's stockholders will be diluted. Moreover, the terms
upon which the Company will be able to obtain additional equity capital may be
adversely affected because the holders of outstanding warrants and options can
be expected to exercise them at a time when the Company would, in all
likelihood, be able to obtain any needed capital on terms more favorable than
the exercise terms provided by such outstanding securities. In the event of the
exercise of a substantial number of warrants and options, within a reasonably
short period of time after the right to exercise commences, the resulting
increase in the amount of the Company's common stock in the trading market could
substantially adversely affect the market price of the common stock or the
Company's ability to raise money through the sale of equity securities.
16
THE COMPANY DEPENDS ON KEY PERSONNEL AND COULD BE SERIOUSLY HARMED IF IT LOST
THEIR SERVICES.
Cheniere depends on its executive officers for various activities. The Company
does not maintain key person life insurance policies on any of its personnel.
The loss of the services of any of these individuals could seriously harm the
Company. In addition, the Company's future success will depend in part on its
ability to attract and retain additional qualified personnel. Cheniere currently
has 12 full-time employees.
THE COMPANY DEPENDS ON INDUSTRY PARTNERS AND COULD BE SERIOUSLY HARMED IF THEY
DO NOT PERFORM SATISFACTORILY, WHICH IS USUALLY NOT WITHIN THE COMPANY'S
CONTROL.
Because the Company has limited financial resources, it will be largely
dependent on industry partners for the success of its oil and gas exploration
projects for the foreseeable future. Cheniere could be seriously harmed if its
industry partners do not perform satisfactorily on projects that affect it. The
Company often has no control over factors that influence the performance of its
partners.
THE COMPANY IS CONTROLLED BY A SMALL NUMBER OF PRINCIPAL STOCKHOLDERS WHO MAY
EXERCISE A PROPORTIONATELY LARGER INFLUENCE ON CHENIERE THAN ITS STOCKHOLDERS
WITH SMALLER HOLDINGS.
Cheniere is controlled by a small number of principal stockholders who may do
things that are not in the interests of the Company's stockholders with smaller
holdings. BSR Investments, Ltd. (BSR) owns approximately 11% of the outstanding
common stock. BSR is controlled by the mother of Charif Souki, chairman of
Cheniere's board of directors. Accordingly, it is likely that BSR will have
significant influence on the election of Cheniere's directors and on its
management, operations and affairs, including the ability to prevent or cause a
change in control of the Company.
ANTI-TAKEOVER PROVISIONS OF THE CERTIFICATE OF INCORPORATION, BYLAWS AND
DELAWARE LAW COULD ADVERSELY IMPACT A POTENTIAL ACQUISITION BY THIRD PARTIES
THAT MAY ULTIMATELY BE IN THE FINANCIAL INTERESTS OF THE COMPANY'S SHAREHOLDERS.
Cheniere's certificate of incorporation, bylaws and the Delaware general
corporation law contain provisions that may discourage unsolicited takeover
proposals. These provisions could have the effect of inhibiting fluctuations in
the market price of the Company's shares that could result from actual or
rumored takeover attempts, preventing changes in its management or limiting the
price that investors may be willing to pay for shares of common stock. These
provisions, among other things, authorize the board of directors to designate
the terms of and to issue new series of preferred stock, to limit the personal
liability of directors, to require the Company to indemnify directors and
officers to the fullest extent permitted by applicable law and to impose
restrictions on business combinations with some interested parties.
A SIGNIFICANT PORTION OF THE VALUE OF THE COMPANY IS DERIVED FROM ITS OWNERSHIP
INTEREST IN GRYPHON, OVER WHICH THE COMPANY EXERCISES NO DAY-TO-DAY CONTROL.
Cheniere owns 100% of the common stock of Gryphon (36.8% effective ownership
after conversion of Gryphon's preferred stock), and a significant portion of the
Company's value is derived from this investment. However, Cheniere is a passive
investor; it does not participate in the day-to-day management of Gryphon and
has no ability to effect a change of control of Gryphon. Accordingly, Gryphon's
management team could make business decisions without Cheniere's consent that
could impair the value of Cheniere's investment in Gryphon.
17
ITEM 3. LEGAL PROCEEDINGS
There are no material legal proceedings currently pending against the Company.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
The Company held a special meeting of its stockholders on October 16, 2000. The
purpose of the meeting was to take a vote of the stockholders concerning a
proposed one-for-four reverse stock split. Information concerning the proposal
was distributed to all stockholders of record as of September 11, 2000 in a
proxy statement dated September 18, 2000. There were 43,989,572 pre-stock split
shares of common stock outstanding and eligible to vote as of the record date of
September 11, 2000. The results of voting on the reverse stock split is
summarized as follows:
Votes for the reverse split 29,161,146
Votes against the reverse stock split 431,671
Abstentions 25,707
18
PART II
ITEM 5. MARKET PRICE OF AND DIVIDENDS ON THE REGISTRANT'S COMMON EQUITY AND
RELATED STOCKHOLDER MATTERS
Beginning on March 5, 2001, the common stock of the Company has traded on The
American Stock Exchange under the symbol CXY. Between December 14, 2000 and
March 2, 2001, Cheniere's common stock traded on the OTC Bulletin Board under
the symbol CHEX.
Between April 11, 1997 and December 13, 2000, the common stock of the Company
traded on The Nasdaq SmallCap Market under the symbol CHEX. From the time the
Company first traded publicly until April 11, 1997, the Company's common stock
traded on the OTC Bulletin Board. The table below presents the high and low
daily closing sales prices of the common stock, as reported by the Nasdaq
SmallCap Market and the OTC Bulletin Board, for each quarter during 1999 and
2000, and for a portion of the Company's current quarter, as reported by the OTC
Bulletin Board and The American Stock Exchange.
High Low
------ -----
Three Months Ended
March 31, 1999 $8.00 $3.50
June 30, 1999 $7.00 $3.50
September 30, 1999 $8.50 $4.75
December 31, 1999 $5.63 $1.63
Three Months Ended
March 31, 2000 $4.57 $3.91
June 30, 2000 $4.00 $2.13
September 30, 2000 $3.30 $2.91
December 31, 2000 $2.27 $1.98
Three Months Ended
March 31, 2001 $3.38 $2.09
As of March 30, 2001, there were 12,797,393 shares of the Company's common stock
outstanding held by approximately 2,800 beneficial owners.
The Company has never paid a cash dividend on its common stock. The Company
currently intends to retain earnings to finance the growth and development of
its business and does not anticipate paying any cash dividends on the common
stock in the foreseeable future. Any future change in the Company's dividend
policy will be made at the discretion of the Company's board of directors in
light of the financial condition, capital requirements, earnings and prospects
of the Company, and any restrictions under any credit agreements, as well as
other factors the board of directors deems relevant.
With respect to equity securities sold by the Company during the fourth quarter
of 2000 that were not registered under the Securities Act of 1933, as amended
(Securities Act), see Liquidity and Capital Resources - Private Placements of
Equity under Item 7 of this report.
ITEM 6. SELECTED FINANCIAL DATA
Selected financial data set forth below are derived from the Company's audited
Consolidated Financial Statements for the periods indicated, except for the data
as of December 31, 1996 and for the four months ended December 31, 1996, which
is derived from the Company's unaudited financial data. The financial data
should be read in conjunction with the Management's Discussion and Analysis of
Financial Condition and Results of Operations and the Company's Consolidated
Financial Statements and Notes thereto included elsewhere in this report.
19
FOR THE YEAR ENDED FOR THE FOUR MONTHS ENDED
DECEMBER 31, DECEMBER 31,
------------------------------------------- ----------------------------
2000 1999 1998 1997 1996(1)
------------ ------------ ------------ ----------- -------------
Revenues $ 5,320,432 $ 1,614,055 $ -- $ -- $ --
Production Costs 388,637 128,859 -- -- --
Depreciation, depletion and amortization 3,371,383 1,361,644 39,171 2,936 2,695
General and administrative expenses 1,938,659 1,908,805 1,619,307 444,087 189,635
Loss from operations (378,247) (1,785,253) (1,658,478) (447,023) (192,330)
Interest income (expense) 23,916 31,530 20,634 58,662 (1,223)
Equity in net loss of affiliate (2) (426,649) -- -- -- --
Net loss (780,980) (1,753,723) (1,637,844) (388,361) (193,553)
Net loss per share (basic and diluted) (3) (0.07) (0.27) (0.41) (0.11) (0.07)
Cash dividends per share $ -- $ -- $ -- $ -- $ --
Weighted average shares outstanding (3) 10,732,678 6,449,104 4,003,864 3,587,032 2,650,342
FOR THE PERIOD ENDED
AUGUST 31,
-----------------------------
1997 1996
------------- -------------
Revenues $ -- $ --
Production Costs -- --
Depreciation, depletion and amortization 8,268 3,603
General and administrative expenses 1,705,193 100,211
Loss from operations (1,713,461) (103,814)
Interest income (expense) 36,993 (18,033)
Equity in net loss of affiliate (2) -- --
Net loss (1,676,468) (121,847)
Net loss per share (basic and diluted) (3) (0.55) (0.06)
Cash dividends per share $ -- $ --
Weighted average shares outstanding (3) 3,035,980 2,152,735
DECEMBER 31,
---------------------------------------------------------------------------------
2000 1999 1998 1997 1996 (1)
-------------- ------------- ------------- ------------- -------------
Cash $ 1,888,562 $ 1,175,950 $ 143,868 $ 787,523 $ 2,419,264
Oil and gas properties, proved, net 6,727,613 9,459,041 -- -- --
Oil and gas properties, unproved 18,253,731 20,648,923 20,000,425 16,534,054 6,000,000
Total assets 34,665,618 34,481,275 20,840,474 17,705,627 8,476,710
Long-term notes payable -- -- 2,025,020 2,025,000 --
Total liabilities 1,604,410 6,735,537 4,523,144 4,285,599 262,798
Total stockholders' equity 33,061,208 27,745,738 16,317,330 13,420,028 8,213,912
AUGUST 31,
----------------------------------
1997 1996
------------- ------------------
Cash $ 234,764 $ 1,093,180
Oil and gas properties, proved, net -- --
Oil and gas properties, unproved 13,500,000 4,000,000
Total assets 13,841,712 5,145,310
Long-term notes payable -- --
Total liabilities 888,291 718,855
Total stockholders' equity 12,953,421 4,426,455
(1) On April 7,1998, the Company's board of directors approved a change in
fiscal year-end. The change in year-end resulted in a transition period from
September 1, 1997 to December 31, 1997.
(2) Represents the Company's equity in the net loss of Gryphon. See Note 6 to
the Company's Consolidated Financial Statements.
(3) Net loss per share and weighted average shares outstanding have been
restated to give effect to the one-for-four reverse stock split which was
effective in October 2000. See Note 2 to Consolidated Financial Statements.
20
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
GENERAL
Cheniere Operating was incorporated in Delaware in February 1996 for the purpose
of engaging in the oil and gas exploration business, initially on the Louisiana
Gulf Coast. On July 3, 1996, Cheniere Operating underwent a reorganization
whereby Bexy Communications, Inc., a publicly held Delaware corporation (Bexy),
received 100% of the outstanding shares of Cheniere Operating, and the former
stockholders of Cheniere Operating received approximately 93% of the issued and
outstanding Bexy shares. As a result of the share exchange, a change in the
control of the Company occurred. The transaction was accounted for as a
recapitalization of Cheniere Operating. Bexy spun off its existing assets and
liabilities to its original stockholders and changed its name to Cheniere
Energy, Inc.
On April 7, 1998, the Company's board of directors approved a change in fiscal
year-end. The change in year-end resulted in a transition period from September
1, 1997 to December 31, 1997.
PRODUCTION AND PRODUCT PRICES
Information concerning the Company's production and average prices received for
the years ended December 31, 2000 and 1999 is presented in the following table.
Cheniere commenced its production of oil and gas on September 9, 1999.
YEAR ENDED DECEMBER 31,
------------------------------------
2000 1999
--------------- ---------------
Production
Oil (Bbls) 3,703 2,975
Gas(Mcf) 1,459,897 633,432
Gas equivalents (Mcfe) 1,482,117 651,282
Average sales prices:
Oil (per Bbl) $ 29.78 $ 23.18
Gas (per Mcf) $ 3.79 $ 2.59
RESULTS OF OPERATIONS - COMPARISON OF THE FISCAL YEARS ENDED DECEMBER 31, 2000
AND 1999
The Company's financial results for the year ended December 31, 2000, reflect a
loss of $780,980 or $0.07 per share (both basic and diluted), as compared to a
loss of $1,753,723, or $0.27 per share (both basic and diluted), for the fiscal
year ended December 31, 1999.
Cheniere commenced production of oil and gas on September 9, 1999. Accordingly,
oil and gas revenues and related costs and expenses include a full year of
production in 2000, compared to approximately four months of production in 1999.
As a result, revenues totaled $5,320,432 for the year ended December 31, 2000,
compared to $1,614,055 in 1999; production costs were $388,637 in 2000 compared
to $128,859 in 1999; and depreciation, depletion and amortization (DD&A)
increased to $3,371,383 in 2000 from $1,361,644 in 1999.
Gross general and administrative (G&A) expenses totaled $4,366,207 in 2000,
compared to $2,868,805 in 1999. In mid-1999, Cheniere licensed 8,800 square
miles of seismic data (the Fairfield Database) and doubled the number of its
employees, adding management and exploration professionals to exploit its
expanded database. In October 2000, Cheniere transferred to Gryphon the
Fairfield Database, other assets and liabilities and substantially all of the
management and technical team assembled in mid-1999 to exploit the Fairfield
Database. As a result, salaries, benefits and consulting expenses increased to
$2,735,337 for 2000, compared to $1,674,200 for 1999. In connection with the
October 2000 Gryphon Transaction, Cheniere issued its financial advisers
warrants to purchase 125,000 shares of common stock, valued at $165,000. Also in
2000, Cheniere received management fees totaling $1,684,193, of which $988,548
was recorded as a recovery of G&A expenses. The management fees were received
from the Company's industry partner, Samson, beginning in March 2000 and running
through October 11, 2000, at which time the related exploration agreement was
assigned to Gryphon. G&A expenses, net of recoveries, were $3,377,659 in 2000
compared with $2,868,805 in 1999. Cheniere capitalizes as oil and gas property
costs that portion of G&A expenses directly related to its exploration
21
and development activities. Cheniere capitalized $1,439,000 in 2000 compared to
$960,000 in 1999, the change being a direct result of the increased level of
exploration activity. G&A expenses, net of recoveries and amounts capitalized,
were $1,938,659 and $1,908,805 in 2000 and 1999, respectively.
Cheniere accounts for its investment in Gryphon using the equity method of
accounting. Cheniere does not participate in the day-to-day management of
Gryphon, does not exercise control over Gryphon and cannot effect a change in
the management of Gryphon. Cheniere's equity share of Gryphon's earnings
(losses) for the period from October 11, 2000 through December 31, 2000 was
$426,649, calculated by applying Cheniere's 100% common stock ownership interest
to Gryphon's net income of $19,003 and reducing such result for Gryphon's
preferred dividend arrearages ($445,652). At such time as Warburg converts its
preferred shares to common shares, Cheniere's equity share of Gryphon's earnings
will be calculated at 36.8%.
RESULTS OF OPERATIONS - COMPARISON OF THE FISCAL YEARS ENDED DECEMBER 31, 1999
AND 1998
The Company's financial results for the year ended December 31, 1999, reflect a
loss of $1,753,723 or $0.27 per share (both basic and diluted), as compared to a
loss of $1,637,844, or $0.41 per share (both basic and diluted), for the fiscal
year ended December 31, 1998. The Company began its initial production of oil
and gas in September 1999. Oil and gas revenues totaled $1,614,055 for 1999, and
related production costs were $128,859.
DD&A increased to $1,361,644 in 1999 from $39,171 in 1998 principally due to the
inclusion in 1999 of $1,200,186 related to proved oil and gas properties.
G&A expenses increased to $1,908,805 in 1999 compared to $1,619,307 in 1998.
During 1999, Cheniere licensed 8,800 additional square miles of seismic data and
doubled the number of its employees, adding management and exploration
professionals to exploit its expanded database. As a result, salaries, benefits
and consulting expenses increased to $1,674,200 for 1999 compared with $773,485
in 1998. Additionally, the related expansion of office facilities increased
office rent and occupancy expenses to $264,971 in 1999 from $52,558 in 1998.
Legal and professional fees decreased to $286,716 in 1999 from $938,766 in 1998,
largely due to the inclusion in 1998 of $817,870 of nonrecurring expenses
related to arbitration proceedings. Investor relations and travel expenses
increased to $293,623 in 1999 from $49,691 in 1998 as Cheniere engaged outside
consultants to assist in broadening investor interest in the Company;
approximately $100,000 of the 1999 expenses relate to the non-cash issuance of
warrants to the Company's outside consultants. Cheniere capitalizes as oil and
gas property costs that portion of G&A related to its exploration and
development activities. Cheniere capitalized $960,000 of such G&A expenses in
1999 and $444,000 in 1998.
At December 31, 1999, the cost of Cheniere's oil and gas properties exceeded its
ceiling test limitation by $1,888,912. Increases in the prices of oil and gas
subsequent to year-end were significant enough to fully eliminate the need for a
write-down of the Company's oil and gas properties. For further discussion, see
Note 2 - Summary of Significant Accounting Policies.
LIQUIDITY AND CAPITAL RESOURCES
The Company anticipates that future liquidity requirements will be met by cash
balances, cash flows from operating activities, borrowings from financial
institutions, debt offerings, additional offerings of the Company's equity
securities, sales of portions of its working interest in the prospects within
its exploration program, sale to an industry partner of a participation in the
Company's exploration program, including sale of a license to the approximate
6,800 square miles of seismic data in the Offshore Texas Project Area, and/or
sale of all or a portion of the Company's producing oil and gas properties.
Cash Flow from Operating Activities
Cheniere commenced production of oil and gas in September 1999. Cash flow from
operations (before changes in operating assets and liabilities) for the year
ended December 31, 2000 totaled $3,151,302. In October 2000, Cheniere paid in
full the $1,047,514 balance outstanding under its platform financing facility.
Cash flows from Cheniere's producing oil and gas properties, which were
previously dedicated to the repayment of this obligation, are now available to
the Company for the funding of its operations.
Private Placements of Equity
Since its inception, Cheniere's primary source of financing for operating
expenses and investments in its exploration program has been the sale of its
equity securities. Through December 31, 2000, the Company has issued 12,547,393
shares of its common stock, generating net proceeds of $38,597,631. During 2000,
the Company raised $5,373,650, net of offering costs, from the sale of units
(common stock and warrants) to accredited investors pursuant to Regulation D,
through the exercise of warrants, and through the issuance of common stock in
exchange for a short-term note payable. Proceeds of the offerings were used for
the acquisition of leases and other exploration costs, for the repayment of
short-term notes payable and for general corporate purposes.
22
In February and March 2000, the Company issued to three investors 373,000 units
at a price of $3.00 per unit, each unit representing one share of common stock
and one warrant to purchase a share of common stock. Warrants issued in
connection with these sales of units are exercisable at a price of $4.00 per
share on or before the second anniversary of the date the units were sold. These
issuances were made in reliance on the exemption from registration provided by
Section 506 of Regulation D. Net proceeds were $1,020,000 after payment of
$99,000 in selling commissions.
In March 2000, the Company issued to nine investors 234,375 shares pursuant to
the exercise of warrants at an exercise price of $4.00 per share. These
issuances were made in reliance on the exemption from registration provided by
Section 506 of Regulation D. Net proceeds were $937,500.
Also in March 2000, Cheniere issued 16,667 shares of common stock to one Company
in exchange for $50,000 of geophysical consulting services. In April 2000,
Cheniere issued 50,000 shares to a drilling Company in connection with an
adjustment to the price of shares previously issued for drilling services
rendered. These issuances were made in reliance on the exemption from
registration provided by Section 4(2) of the Securities Act of 1933.
In April 2000, Cheniere issued 20,233 units to ten existing stockholders
pursuant to price adjustment provisions of their subscription agreements. These
units represented 20,233 shares of common stock and warrants to purchase 10,117
shares of common stock at an exercise price of $6.00 per share on or before
April 13, 2003. These issuances were made in reliance on the exemption from
registration provided by Section 506 of Regulation D.
As a selling commission related to a 1999 private placement of securities,
Cheniere issued to an individual in April 2000 warrants to purchase 25,000
shares of common stock at an exercise price of $6.00 per share on or before June
30, 2002.
In September 2000, the Company issued to the holder of its bridge notes warrants
to purchase 250,000 shares of common stock at an exercise price of $4.00 per
share on or before September 6, 2003. Cheniere also issued 250,000 shares to the
note holder in September 2000, at a price of $2.00 per share, in satisfaction of
$500,000 of the bridge notes.
In December 2000, the Company consummated a private placement of 1,550,000 units
consisting of one share of common stock, $.003 par value per share, and one
warrant to purchase one-sixth of a share of common stock at an exercise price of
$3.00 per share. The units were sold pursuant to Regulation D to approximately
twenty-six accredited investors, including members of the Company's management
and affiliates who purchased an aggregate of $475,000. The total purchase price
of the units sold was $3,100,000. Proceeds of the offering, net of offering
costs, were approximately $2,866,150 and will be used to fund exploration
activities and for other general corporate purposes. Petrie Parkman & Co. acted
as financial advisor to the Company in connection with the private placement,
and principals of Petrie Parkman & Co. purchased an aggregate of $500,000 in the
offering. The holders of the shares of common stock issued in this offering were
granted certain registration rights.
Short-Term Promissory Notes
At December 31, 2000, Cheniere had no outstanding debt obligations. At December
31, 1999, Cheniere had outstanding short-term notes payable of $4,963,213. Three
financing facilities comprised the balance: platform financing of $3,090,643,
well services financing of $1,117,570 and December 1997 bridge financing notes
of $755,000. The terms of each of these facilities and of others that were
utilized within the three years ended December 31, 2000, are described in the
following paragraphs.
April 2000 - $2,000,000 Bridge Financing - In April 2000, the Company
established a bridge financing facility which provided for: borrowings of up to
$2,000,000 bearing interest at a rate equal to LIBOR plus 2%, a placement fee
equal to 2% of the commitment amount, the issuance of warrants to purchase
250,000 shares of common stock at an exercise price of $4.00 per share on or
before September 6, 2003, and conversion of the notes payable into common stock,
at Cheniere's election, at a price per share equal to $2.00 per share. Cheniere
borrowed an aggregate of $2,000,000 under the facility during 2000. In September
2000, the Company repaid $500,000 in cash and issued 250,000 shares to satisfy
an additional $500,000. In December 2000, Cheniere repaid the remaining balance
of $1,000,000 plus accrued interest.
September 1999 - $3,100,000 Platform Financing - On September 1, 1999, Cheniere
established a $3,100,000 financing facility to fund a production platform and
other exploration and development costs in the West Cameron Block 49 area.
Borrowings under the facility were repaid from Cheniere's share of net cash flow
from production through the West Cameron Block 49 platform. The note was secured
by Cheniere's oil and gas properties and had a maturity date of June 30, 2000.
Financing costs included interest at 10% per annum and a 5% net profit interest
in the initial two wells producing through the platform. At December 31, 1999,
the outstanding balance under the facility was $3,090,643. During 2000, the
Company borrowed an additional $605,000 under the same facility and repaid all
principal and interest due under the facility.
23
December 1999 - $1,117,570 Well Services Financing - In December 1999, Cheniere
entered into a financing agreement with a supplier of well services to
consolidate and convert trade accounts payable balances into a short-term
secured note payable. Interest was payable at 10% per annum. The note was
secured by Cheniere's oil and gas properties and matured on July 5, 2000. At
December 31, 1999, the outstanding balance was $1,117,570, which balance and all
related interest were repaid during 2000.
December 1997 - $4,000,000 Bridge Financing - In December 1997, Cheniere
completed the private placement of a $4,000,000 bridge financing. The notes
payable issued by Cheniere had an initial maturity date of March 15, 1998, which
was extended ultimately to March 15, 2000, when the then-remaining balance was
paid. In connection with the issuance of the notes payable and with various
extensions in the maturity dates, the Company has issued 70,273 shares of common
stock and warrants to purchase 925,809 shares of common stock at prices ranging
from $4.00 to $7.00 per share. The notes bore interest at rates ranging from
LIBOR plus 4% to LIBOR plus 6% (approximately 12.14% at December 31, 1999).
Exploration Agreement
On March 10, 2000, Cheniere entered into an exploration agreement with an
industry partner. Under the terms of the agreement, Cheniere's exploration
partner acquired an option to participate at a 50% working interest level in any
drilling prospects generated by Cheniere over the subsequent eighteen-month
period within a defined area of mutual interest in the Gulf of Mexico. Pursuant
to the exploration agreement, Cheniere receives a management fee of $230,000 per
month over the eighteen-month term of the agreement. In addition, Cheniere's
partner pays a disproportionate share of the cost of leasing and of the initial
test well on each prospect. In October 2000, Cheniere assigned its rights and
obligations under this agreement to Gryphon in connection with the Gryphon
Transaction.
Exploration Funding
On October 11, 2000, Cheniere completed a transaction with Warburg to fund its
exploration program on approximately 8,800 square miles of seismic data in the
Gulf of Mexico (the Louisiana Data Set) through a newly formed affiliated
company, Gryphon. Cheniere contributed selected assets and liabilities in
exchange for 100% of the common stock of Gryphon and $2,000,000 in cash (36.8%
effective interest after conversion of preferred stock). Such assets include:
the Louisiana Data Set, certain offshore leases, a prospect then being drilled,
its exploration agreement with an industry partner and certain other assets and
liabilities. The net book value of the assets and liabilities contributed was
$7,065,919, which consisted of assets of $9,115,963, which primarily consisted
of unproved oil and gas properties and liabilities of $2,050,044, which
primarily consisted of account payable. Warburg contributed $25,000,000 and
received preferred stock, with an 8% cumulative dividend, convertible into 63.2%
of Gryphon's common stock.
Cheniere and Warburg also have the option, in connection with subsequent capital
calls made by Gryphon, to contribute up to an additional $75,000,000 to Gryphon,
proportionate to their respective ownership interests. Under the terms of the
agreement governing these additional contributions, in the event that either
Cheniere or Warburg elects not to participate in any additional contribution,
the other investor has the option to purchase the non-participating investor's
proportionate share. Assuming (i) that Gryphon makes subsequent capital calls
for an aggregate of $75,000,000, (ii) that Cheniere elects not to participate in
any of the capital calls and (iii) that Warburg elects to purchase all of
Cheniere's proportionate share, the Company's effective interest in Gryphon,
after giving effect to the conversion of Gryphon's preferred stock, will be
reduced to 12.7%. Cheniere accounted for the contribution of net assets at its
historical cost, whereby the net amount of such assets and liabilities less the
$2,000,000 in cash was reclassified to investment in affiliate. No gain or loss
was recognized at the time of contribution, primarily due to Cheniere's
commitment to provide additional funding described above.
Cheniere accounts for its investment in Gryphon using the equity method of
accounting. Cheniere does not participate in the day-to-day management of
Gryphon, does not exercise control over Gryphon and cannot effect a change in
the management of Gryphon. Cheniere's equity share of Gryphon's earnings
(losses) for the period from October 11, 2000 through December 31, 2000 was
$426,649, calculated by applying Cheniere's 100% common stock ownership interest
to Gryphon's net income of $19,003 and reducing such result for Gryphon's
preferred dividend arrearages ($445,652). At such time as Warburg converts its
preferred shares to common shares, Cheniere's equity share of Gryphon's earnings
will be calculated at 36.8%.
24
Seismic Reprocessing
Between June 2000 and October 2000, Cheniere acquired licenses to approximately
6,800 miles of seismic data primarily in the shallow waters offshore Texas and
also in the West Cameron area in the Gulf of Mexico (the Offshore Texas Project
Area) in separate transactions with Seitel Data Ltd., a division of Seitel Inc.,
and JEBCO Seismic, L.P. Cheniere has committed to reprocess all of the data from
the Offshore Texas Project Area at a cost of approximately $8,500,000, payable
in installments beginning in October 2000 and continuing through the final
delivery of reprocessed data, which is expected to occur by December 2001.
Recoverability of Investment in Oil and Gas Properties
The recoverability of the Company's unevaluated oil and gas properties is
dependent on future events, including obtaining adequate financing for its
exploration and development program, the successful reprocessing of the 3D
seismic data in the Offshore Texas Project Area, the successful completion of
its planned drilling program, and the achievement of a level of operating
revenues that is sufficient to support the Company's cost structure. At various
times during the life of the Company to date, it has been necessary for the
Company to raise additional capital through private placements of debt or equity
financing. When such a need has arisen, the Company has met it successfully. It
is management's belief that it will continue to be able to meet its needs for
additional capital as such needs arise in the future.
Cheniere's needs for additional financing include the following:
. Additional capital will be required to pay for Cheniere's share of costs
relating to the drilling of prospects and development of those that are
successful, to exercise lease options, and to acquire additional oil and gas
leases. The total amount of the Company's capital needs will be determined in
part by the number of prospects generated within its exploration program and by
the working interest that the Company retains in those prospects.
. The Company will need funds for the payment of approximately $8,000,000
related to future deliveries of reprocessed seismic data through December 2001.
. The Company may need capital to fund its pro-rata share of the capital calls
by Gryphon that are approved by Gryphon's Board of Directors. The Company's
share of such future capital calls could total up to $27,600,000. If the Company
elects not to fund its pro-rata portion of such capital calls, and Warburg funds
its portion, as they would be entitled, the Company will suffer dilution of its
holdings in Gryphon. If the Company subscribes to its pro-rata portion of such
capital calls but fails to fund, it would lose its ability to subscribe to any
future capital calls and would suffer dilution of its holdings in Gryphon. It is
anticipated that Gryphon will make cash calls for additional funds during 2001.
. The Company will need funds for the payment of a transfer fee related to the
assignment to Gryphon of its seismic license over the Offshore Louisiana Project
Area. Cheniere is obligated to pay a transfer fee of up to $2,500,000, in ten
installments of $250,000, which would become payable after one month of
production from each of ten separate successful wells completed by Gryphon
within the data set.
. Should the Company choose to make an acquisition of producing oil and gas
properties, it is likely that such an acquisition would require that some
portion of the purchase price be paid in cash, and thus would create the need
for additional capital.
Additional capital could be obtained from a combination of funding sources.
These potential funding sources include:
. cash flow from operating activities,
. borrowings from financial institutions,
. debt offerings, which would increase the Company's leverage and add to its
need for cash to service such debt,
. additional offerings of the Company's equity securities, which would cause
dilution of its common stock,
. sales of portions of its working interest in the prospects within its
exploration program, which would reduce future revenues from its exploration
program,
25
. sale to an industry partner of a participation in the Company's exploration
program, including sale of a license to the approximate 6,800 square miles of
seismic data in the Offshore Texas Project Area, which would reduce future
revenues from its exploration program, and
. sale of all or a portion of the Company's producing oil and gas properties,
which would reduce future revenues.
Cheniere's ability to raise additional capital will depend on the results of its
operations and the status of various capital and industry markets at the time
such additional capital is sought. Accordingly, there can be no assurances that
capital will be available to the Company from any source or that, if available,
it will be on terms acceptable to the Company.
New Accounting Pronouncements
In June 1998, the Financial Accounting Standards Board (FASB) issued Statement
of Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities. In June 1999, the FASB extended the adoption
date of SFAS 133 until January 1, 2001, through the issuance of SFAS No. 137,
Deferral of the Effective Date of SFAS 133. In June 2000, the FASB issued SFAS
No. 138, Accounting for Certain Derivative Instruments and Certain Hedging
Activities, which also amended SFAS 133. SFAS 133, as amended requires that
companies recognize all derivative instruments as either assets or liabilities
on the balance sheet and measure those instruments at fair value. Changes in the
fair value of derivatives are recorded each period in current earnings or other
comprehensive income depending on their designation, their intended use, or
their ability to qualify as hedges. The Company adopted SFAS 133 in the first
quarter of 2001; such adoption did not have a material impact on its financial
statements.
In December 1999, the Securities and Exchange Commission issued Staff Accounting
Bulletin (SAB) No. 101, Revenue Recognition in Financial Statements. SAB No. 101
was implemented in 2000 and did not have a material effect on the Company's
financial statements.
OTHER DEVELOPMENTS
Cheniere received notice on May 15, 2000 from The Nasdaq Stock Market stating
that the Company was not in compliance with certain requirements related to the
listing of its shares on The Nasdaq SmallCap Market. Specifically, the market
price of the Company's common stock had fallen below $1.00 per share. On
September 21, 2000, Cheniere appeared before a Nasdaq Listing Panel and
requested an exception to the requirement. Nasdaq granted such an exception,
specifying that Cheniere must achieve a minimum bid price of $1.00 per share by
October 23, 2000 and maintain such a bid price for at least 10 consecutive
trading days thereafter. At a special meeting of the Company's stockholders held
on October 16, 2000, the stockholders approved a one-for-four reverse stock
split. The reverse stock split became effective on October 18, 2000 and reduced
Cheniere's issued and outstanding shares from 43,989,572 shares to approximately
10,997,393 shares. The closing bid price exceeded $1.00 per share every day
following the reverse split.
Nevertheless, on December 13, 2000, Nasdaq notified the Company that its common
stock would be delisted from the Nasdaq SmallCap Market effective at the open of
business on December 14, 2000. Effective December 14, 2000, the Company's common
stock began trading on the OTC Bulletin Board under the symbol CHEX. The Company
appealed Nasdaq's ruling, and contemporaneously with the appeal, applied for
listing on The American Stock Exchange. When the Company's listing application
was accepted by The American Stock Exchange, it discontinued the appeals process
with Nasdaq. Cheniere's common stock began trading on The American Stock
Exchange on March 5, 2001 under the symbol CXY.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The Company produces and sells natural gas, crude oil and condensate. As a
result, the Company's financial results can be significantly affected as these
commodity prices fluctuate widely in response to changing market forces. The
Company has not entered into any derivative transactions.
26
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX TO FINANCIAL STATEMENTS
CHENIERE ENERGY, INC. AND SUBSIDIARIES
Report of Independent Accountants............................... 28
Consolidated Balance Sheet...................................... 29
Consolidated Statement of Operations............................ 30
Consolidated Statement of Stockholders' Equity.................. 31
Consolidated Statement of Cash Flows............................ 32
Notes to Consolidated Financial Statements...................... 33
Supplemental Information to Consolidated Financial Statements... 48
27
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and
Stockholders of Cheniere Energy, Inc:
In our opinion, the consolidated financial statements listed in the index
appearing under Item 14(a)(1) on page 55 present fairly, in all material
respects, the financial position of Cheniere Energy, Inc. and its subsidiaries
at December 31, 2000 and 1999, and the results of their operations and their
cash flows for each of the three years in the period ended December 31, 2000 in
conformity with accounting principles generally accepted in the United States of
America. These financial statements are the responsibility of the Company's
management; our responsibility is to express an opinion on these financial
statements based on our audits. We conducted our audits of these statements in
accordance with auditing standards generally accepted in the United States of
America, which 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, assessing the
accounting principles used and significant estimates made by management, and
evaluating the overall financial statement presentation. We believe that our
audits provide a reasonable basis for our opinion.
As more fully described in Note 13, the recoverability of the Company's
unevaluated oil and gas properties is dependent on future events, including
obtaining additional funding for its completion and development program, its
successful reprocessing of 3D seismic data and the successful completion of its
planned development program. Management's plans in regard to this matter are
also described in Note 13.
PRICEWATERHOUSECOOPERS LLP
Houston, Texas
March 30, 2001
28
CHENIERE ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
December 31, December 31,
ASSETS 2000 1999
------ ----------------- -----------------
CURRENT ASSETS
Cash $ 1,888,562 $ 1,175,950
Accounts Receivable 851,706 906,569
Debt Issuance Costs, net -- 138,909
Prepaid Expenses 98,532 1,223,864
------------ ------------
Total Current Assets 2,838,800 3,445,292
OIL AND GAS PROPERTIES, full cost method
Proved Properties, net 6,727,613 9,459,041
Unproved Properties, not subject to amortization 18,253,731 20,648,923
------------ ------------
Total Oil and Gas Properties 24,981,344 30,107,964
FIXED ASSETS, net 206,204 928,019
INVESTMENT IN UNCONSOLIDATED AFFILIATE 6,639,270 --
------------ ------------
Total Assets $ 34,665,618 $ 34,481,275
============ ============
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts Payable $ 1,472,293 $ 1,589,596
Accrued Liabilities 132,117 182,728
Notes Payable -- 4,963,213
------------ ------------
Total Current Liabilities 1,604,410 6,735,537
COMMITMENTS AND CONTINGENCIES (NOTE 12)
STOCKHOLDERS' EQUITY
Common Stock, $.003 par value
Authorized: 120,000,000 shares
Issued and Outstanding: 12,547,393 shares at December 31, 2000
and 10,053,118 shares at December 31, 1999 37,642 30,159
Preferred Stock, $.0001 par value
Authorized: 5,000,000 shares
Issued and Outstanding: none -- --
Additional Paid-in-Capital 39,382,789 33,293,822
Accumulated Deficit (6,359,223) (5,578,243)
------------ ------------
Total Stockholders' Equity 33,061,208 27,745,738
------------ ------------
Total Liabilities and Stockholders' Equity $ 34,665,618 $ 34,481,275
============ ============
The accompanying notes are an integral part of these financial statements.
29
CHENIERE ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF OPERATIONS
Year Ended December 31,
---------------------------------------------------
2000 1999 1998
---------------- ---------------- ----------------
Revenues
Oil and Gas Sales $ 5,320,432 $ 1,614,055 $ --
------------ ------------ ------------
Total Revenues 5,320,432 1,614,055 --
------------ ------------ ------------
Operating Costs and Expenses
Production Costs 388,637 128,859 --
Depreciation, Depletion and Amortization 3,371,383 1,361,644 39,171
General and Administrative Expenses 1,938,659 1,908,805 1,619,307
------------ ------------ ------------
Total Operating Costs and Expenses 5,698,679 3,399,308 1,658,478
------------ ------------ ------------
Income/(Loss) from Operations Before Interest, Income Taxes
and Equity in Net Loss of Unconsolidated Affiliate (378,247) (1,785,253) (1,658,478)
Interest Income 23,916 31,530 20,634
Provision for Income Taxes -- -- --
Equity in Net Loss of Unconsolidated Affiliate (426,649) -- --
------------ ------------ ------------
Net Loss $ (780,980) $ (1,753,723) $ (1,637,844)
============ ============ ============
Net Loss Per Share - Basic and Diluted $ (0.07) $ (0.27) $ (0.41)
============ ============ ============
Weighted Average Number of Shares Outstanding - Basic and Diluted 10,732,678 6,449,104 4,003,864
============ ============ ============
The accompanying notes are an integral part of these financial statements.
30
CHENIERE ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
Common Stock Additional Total
---------------------------- Paid-In Accumulated Stockholders'
Shares Amount Capital Deficit Equity
------------- ----------- ------------ ------------- -------------
Balance - December 31, 1997 3,614,466 $ 10,843 $ 15,595,861 $ (2,186,676) $ 13,420,028
Issuances of Stock 1,128,971 3,387 4,380,265 -- 4,383,652
Expenses Related to Offerings -- -- (168,000) -- (168,000)
Issuance of Warrants -- -- 319,494 -- 319,494
Net Loss -- -- -- (1,637,844) (1,637,844)
------------ ------------ ------------ ------------ ------------
Balance - December 31, 1998 4,743,437 14,230 20,127,620 (3,824,520) 16,317,330
Issuance of Shares in Exchange for Notes 792,590 2,378 2,243,759 -- 2,246,137
Issuance of Warrants -- -- 200,000 -- 200,000
Repricing of Warrants to Extend Bridge Notes -- -- 35,702 -- 35,702
Issuance of Shares in Exchange for Production Payment 146,119 438 399,562 -- 400,000
Issuances of Stock 4,370,972 13,113 11,001,567 -- 11,014,680
Expenses Related to Offerings -- -- (714,388) -- (714,388)
Net Loss -- -- -- (1,753,723) (1,753,723)
------------ ------------ ------------ ------------ ------------
Balance - December 31, 1999 10,053,118 30,159 33,293,822 (5,578,243) 27,745,738
Issuance of Shares in Exchange for Note 250,000 750 499,250 -- 500,000
Issuance of Warrants -- -- 722,800 -- 722,800
Issuances of Stock 2,244,275 6,733 5,199,767 -- 5,206,500
Expenses Related to Offerings -- -- (332,850) -- (332,850)
Net Loss -- -- -- (780,980) (780,980)
------------ ------------ ------------ ------------ ------------
Balance - December 31, 2000 12,547,393 $ 37,642 $ 39,382,789 $ (6,359,223) $ 33,061,208
============ ============ ============ ============ ============
The accompanying notes are an integral part of these financial statements.
31
CHENIERE ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
Year Ended December 31,
---------------------------------------------------
2000 1999 1998
----------------- ----------------- ------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Loss $ (780,980) $(1,753,723) $(1,637,844)
Adjustments to Reconcile Net Loss to
Net Cash Provided by (Used in) Operating Activities:
Depreciation, Depletion and Amortization 3,371,383 1,361,644 39,171
Compensation Paid in Common Stock -- 37,500 --
Non-Cash Expense (Issuance of Warrants) 134,250 100,000 --
Equity in Net Loss of Unconsolidated Affiliate 426,649 -- --
----------- ----------- -----------
3,151,302 (254,579) (1,598,673)
Changes in Operating Assets and Liabilities
Accounts Receivable 54,863 (808,732) 4,493
Subscriptions Receivable -- 500,000 (500,000)
Prepaid Expenses (16,787) (82,734) 1,710
Accounts Payable and Accrued Liabilities 2,014,028 1,249,178 251,378
----------- ----------- -----------
NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES 5,203,406 603,133 (1,841,092)
----------- ----------- -----------
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchases of Fixed Assets (320,362) (999,965) (81,810)
Proceeds from Sales of Oil and Gas Seismic Data -- 275,000 --
Oil and Gas Property Additions (6,561,169) (8,534,225) (2,804,905)
Proceeds from Contribution of Assets to Unconsolidated Affiliate 2,000,000 -- --
----------- ----------- -----------
NET CASH USED IN INVESTING ACTIVITIES (4,881,531) (9,259,190) (2,886,715)
----------- ----------- -----------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Notes Payable or Advances 2,605,000 3,100,000 877,000
Repayment of Notes Payable or Advances (7,068,213) (996,846) (877,000)
Sale of Common Stock 5,156,500 8,438,282 4,252,152
Offering Costs (302,550) (714,388) (168,000)
Debt Issuance Costs -- (138,909) --
----------- ----------- -----------
NET CASH PROVIDED BY FINANCING ACTIVITIES 390,737 9,688,139 4,084,152
----------- ----------- -----------
NET INCREASE (DECREASE) IN CASH 712,612 1,032,082 (643,655)
CASH - BEGINNING OF PERIOD 1,175,950 143,868 787,523
----------- ----------- -----------
CASH - END OF PERIOD $ 1,888,562 $ 1,175,950 $ 143,868
=========== =========== ===========
The accompanying notes are an integral part of these financial statements.
32
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1-ORGANIZATION AND NATURE OF OPERATIONS
Cheniere Energy, Inc., a Delaware corporation, is engaged in exploration for oil
and gas reserves. The terms Cheniere and Company refer to Cheniere Energy, Inc.
and its subsidiaries. Cheniere is a Houston-based company formed for the purpose
of oil and gas exploration, development and exploitation. The Company is
currently engaged in the exploration for oil and natural gas along the Gulf
Coast of Texas and Louisiana, onshore and in the shallow waters of the Gulf of
Mexico. The Company commenced operations in April 1996 by entering into an
exploration agreement with an industry partner to acquire and process seismic
data. Cheniere has acquired two significant seismic database assets: 1) the
Cameron Project and 2) the Offshore Texas Project.
NOTE 2-SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The consolidated financial statements include the accounts of Cheniere Energy,
Inc. and its wholly-owned subsidiaries. Cheniere also owns an effective 36.8%
interest in an affiliated company, Gryphon Exploration Company, and accounts for
this investment using the equity method of accounting. All significant
intercompany accounts and transactions have been eliminated in consolidation.
Oil and Gas Properties
The Company follows the full cost method of accounting for its oil and gas
properties. Under this method, all productive and nonproductive exploration and
development costs incurred for the purpose of finding oil and gas reserves are
capitalized. Such capitalized costs include lease acquisition, geological and
geophysical work, delay rentals, drilling, completing and equipping oil and gas
wells, together with internal costs directly attributable to property
acquisition, exploration and development activities. Interest is capitalized on
oil and gas properties not subject to amortization and in the process of
development. The Company capitalized interest totaling $1,154,099, $415,262 and
$1,058,595 and general and administrative expenses, net of reimbursements,
totaling $743,355, $960,000 and $444,000 for the years 2000, 1999 and 1998,
respectively.
The costs of the Company's oil and gas properties, including the estimated
future costs to develop proved reserves, are depreciated using a composite
units-of-production rate based on estimates of proved reserves. Investments in
unproved properties and major development projects are not amortized until
proved reserves associated with the projects can be determined or until
impairment occurs. If the results of an assessment indicate that the properties
are impaired, the amount of the impairment is added to the capitalized costs to
be amortized. Net capitalized costs are limited to a capitalization ceiling,
calculated on a quarterly basis as the aggregate of the present value,
discounted at 10%, of estimated future net revenues from proved reserves, based
on current economic and operating conditions, plus the lower of cost or fair
market value of unproved properties, less related income tax effects.
The Company's allocation of seismic exploration costs to proved properties
involves an estimate of the total reserves to be discovered in the project. It
is reasonably possible, based on the results obtained from future drilling, that
revisions to this estimate could occur within the next twelve months, which
could affect the Company's capitalization ceiling.
Sales of proved and unproved properties are accounted for as adjustments of
capitalized costs with no gain or loss recognized, unless such adjustments would
significantly alter the relationship between capitalized costs and proved oil
and gas reserves.
33
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Revenue Recognition
Revenues from the sale of oil and gas production are recognized upon passage of
title, net of royalty interests. When sales volumes differ from the Company's
entitled share, an underproduced or overproduced imbalance occurs. To the extent
an overproduced imbalance exceeds the Company's share of the remaining estimated
proved natural gas reserves for a given property, the Company records a
liability. At December 31, 2000 and 1999, the Company had no gas imbalances.
Debt Issuance Costs
Costs incurred in connection with the issuance of debt are capitalized and
amortized into interest expense using the straight line method which
approximates the interest method. (which is then capitalized as a cost of oil
and gas properties) over the term of the related debt. Accumulated amortization
was $849,249 as of December 31, 2000 and $24,382 as of December 31, 1999.
Fixed Assets
Fixed assets are recorded at cost. Repairs and maintenance costs are charged to
operations as incurred. Depreciation is computed using the straight-line method
calculated to amortize the cost of assets over their estimated useful lives,
which range from three to seven years. Upon retirement or other disposition of
property and equipment, the cost and related depreciation is removed from the
accounts and the resulting gains or losses are recorded.
Offering Costs
Offering costs consist primarily of placement fees, professional fees and
printing costs. These costs are charged against the related proceeds from the
sale of common stock in the periods in which they occur.
Income Taxes
Provisions for income taxes are based on taxes payable or refundable for the
current year and deferred taxes on temporary differences between the amount of
taxable income and pretax financial income and between the tax bases of assets
and liabilities and their reported amounts in the financial statements. Deferred
tax assets and liabilities are included in the financial statements at currently
enacted income tax rates applicable to the period in which the deferred tax
assets and liabilities are expected to be realized or settled as prescribed in
Statement of Financial Accounting Standards (SFAS) No. 109, Accounting for
Income Taxes. As changes in tax laws or rates are enacted, deferred tax assets
and liabilities are adjusted through the current period's provision for income
taxes.
Stock-Based Compensation
SFAS No. 123, Accounting for Stock-Based Compensation, encourages, but does not
require, companies to record compensation cost for stock-based employee
compensation plans at fair value. The Company has chosen to continue to account
for stock-based compensation issued to employees using the intrinsic value
method prescribed in Accounting Principles Board (APB) Opinion No. 25,
Accounting for Stock Issued to Employees, and related interpretations.
Accordingly, compensation cost for stock options is measured as the excess, if
any, of the quoted market price of the Company's stock at the date of the grant
over the amount an employee must pay to acquire the stock. The Company grants
options at or above the market price of its common stock at the date of each
grant. The Company accounts for stock-based compensation issued to non-
employees using SFAS No. 123.
Earnings (Loss) Per Share
Earnings (loss) per share (EPS) is computed in accordance with the requirements
of SFAS No. 128, Earnings Per Share. Basic EPS excludes dilution and is computed
by dividing net income (loss) by the weighted average number of shares
outstanding during the period. Diluted EPS reflects potential dilution and is
computed by dividing net income (loss) by the weighted average number of common
shares outstanding during the period increased by the number of additional
common shares that would have been outstanding if the potential common shares
had been issued. Potential dilutive common stock equivalents include stock
options from employee benefit plans and warrants to purchase common stock. Basic
and diluted EPS for all periods presented are the same since the effect of the
Company's options and warrants is antidilutive to its net loss per share under
SFAS No. 128.
34
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Reverse Stock Split
On October 16, 2000, the Company's stockholders approved a one-for-four reverse
stock split, which became effective on October 18, 2000. All per share amounts
and numbers of shares in the financial statements have been restated for the
effect of this reverse stock split.
Cash Equivalents
The Company classifies all investments with original maturities of three months
or less as cash equivalents.
Fair Value of Financial Instruments
The carrying amounts of cash and cash equivalents, accounts receivable and
accounts payable approximate fair value because of the short maturity of those
instruments. The carrying value of the Company's notes payable as of December
31, 1999 is considered to approximate its fair value due to the short-term
nature of the notes.
Commodity Price Risk
The Company produces and sells natural gas, crude oil and condensate. As a
result, the Company's financial results can be significantly affected as these
commodity prices fluctuate widely in response to changing market forces. The
Company has not entered into any hedging transactions. The Company's market risk
with respect to its fixed-rate, short-term notes payable is considered to be
immaterial due to the short-term nature of these instruments.
Concentration of Credit Risk
All of the Company's revenues are derived from a single customer. The Company's
products are commodities and constantly have a readily available market for
sale.
Use of Estimates
The preparation of financial statements in conformity with generally accepted
accounting principles requires that the Company make estimates and assumptions
that affect the amounts reported in the financial statements and the
accompanying notes. Actual results could differ from those estimates. Management
believes its estimates are reasonable.
Reclassifications
Certain prior period amounts have been reclassified to conform to the current
period presentation. These reclassifications had no effect on the Company's net
income or stockholder's equity.
New Accounting Pronouncements
In June 1998, the Financial Accounting Standards Board (FASB) issued Statement
of Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities. In June 1999, the FASB extended the adoption
date of SFAS 133 until January 1, 2001, through the issuance of SFAS No. 137,
Deferral of the Effective Date of SFAS 133. In June 2000, the FASB issued SFAS
No. 138, Accounting for Certain Derivative Instruments and Certain Hedging
Activities, which also amended SFAS 133. SFAS 133, as amended requires that
companies recognize all derivative instruments as either assets or liabilities
on the balance sheet and measure those instruments at fair value. Changes in the
fair value of derivatives are recorded each period in current earnings or other
comprehensive income depending on their designation, their intended use, or
their ability to qualify as hedges. The Company adopted SFAS 133 in the first
quarter of 2001; such adoption did not have a material impact on its financial
statements.
35
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
In December 1999, the Securities and Exchange Commission issued Staff Accounting
Bulletin (SAB) No. 101, Revenue Recognition in Financial Statements. SAB No. 101
was implemented in 2000 and did not have a material effect on the Company's
financial statements.
NOTE 3-FIXED ASSETS
Fixed assets consist of the following:
December 31,
2000 1999
-------------- -------------
Furniture and Fixtures $ 43,391 $ 133,588
Computers and Office Equipment 132,673 544,925
Other 60,977 464,939
------------- ------------
237,041 1,143,452
Less Accumulated Depreciation (30,837) (215,433)
------------- ------------
Fixed Assets, Net $ 206,204 $ 928,019
============= ============
Depreciation expense related to the Company's fixed assets totaled $347,865 in
2000, $161,458 in 1999 and $39,171 in 1998.
NOTE 4-OIL AND GAS PROPERTIES
Investments in oil and gas properties were as follows:
December 31,
2000 1999
----------------- ----------------
Oil and gas properties:
Proved $ 10,951,317 $ 10,659,227
Unproved 18,253,731 20,648,923
----------------- ----------------
29,205,048 31,308,150
Less accumulated depreciation,
depletion and amortization (4,223,704) (1,200,186)
----------------- ----------------
$ 24,981,344 $ 30,107,964
================= ================
36
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Depreciation, depletion and amortization of oil and gas property costs, which
commenced in 1999, totaled $3,023,518 for the year 2000 and $1,200,186 for the
year 1999. Depreciation, depletion and amortization per equivalent Mcf (using an
Mcf-to-barrel conversion factor of 6 to 1) was $2.04 for the year 2000 and $1.84
for the year 1999. All of Cheniere's oil and gas properties are located within
the United States or its territorial waters.
Costs incurred for unproved oil and gas properties were $6,603,296 in 2000 and
$648,498 in 1999.
Subsequent to December 31, 1999, prices for oil and gas increased to levels at
which the Company's capitalized costs did not exceed its capitalization ceiling
at that date. If the capitalization ceiling had been limited to a value
calculated using prices in effect at December 31, 1999, the Company's
capitalized costs would have exceeded its capitalization ceiling by $1,888,912.
The Company has made substantial investments in acquiring, processing and
reprocessing its seismic databases covering a 6,800-square-mile project area
offshore Texas and Louisiana and a 228-square-mile project area onshore and
offshore Louisiana. The costs of these projects become subject to amortization
on a ratable basis as the oil and gas reserves expected to be recovered from the
projects are discovered. The Company began drilling prospects identified within
its seismic databases in 1999. Interpretation of this data is ongoing.
NOTE 5-EXPLORATION AGREEMENT
On March 10, 2000, Cheniere entered into an exploration agreement with an
industry partner. Under the terms of the agreement, Cheniere's exploration
partner acquired an option to participate at a 50% working interest level in any
drilling prospects generated by Cheniere over the subsequent eighteen-month
period within a defined area of mutual interest in the Gulf of Mexico. Pursuant
to the exploration agreement, Cheniere receives a fixed management fee of
$230,000 per month over the eighteen-month term of the agreement. In addition,
Cheniere's partner pays a disproportionate share of the cost of leasing and of
the initial test well on each prospect. Cheniere is the operator of the drilling
program. Management fees received by Cheniere in 2000 totaled $1,684,193 and
were reported as a $988,548 recovery of general and administrative expenses
attributable to generating the management fee and a $695,645 reduction to the
amount of general and administrative expenses which were capitalized as oil and
gas property costs. Each such portion of the management fee was allocated based
on the historical cost and expense structure of the Company. In October 2000,
Cheniere assigned its rights and obligations under this agreement to Gryphon,
its unconsolidated affiliate, in connection with the Company's investment in
Gryphon, as described in Note 6.
NOTE 6-INVESTMENT IN UNCONSOLIDATED AFFILIATE
On October 11, 2000, Cheniere completed a transaction with Warburg to fund its
exploration program on approximately 8,800 square miles of seismic data in the
Gulf of Mexico (the Louisiana Data Set) through a newly formed affiliated
company, Gryphon. Cheniere contributed selected assets and liabilities in
exchange for 100% of the common stock of Gryphon (36.8% voting interest after
conversion of preferred stock) and $2,000,000 in cash. Such assets include: the
Louisiana Data Set, certain offshore leases, a prospect then being drilled, its
exploration agreement with an industry partner and certain other assets and
liabilities. The net book value of the assets and liabilities contributed was
$7,065,919, which consisted of assets of $9,115,963, which primarily consisted
of unproved oil and gas properties and liabilities of $2,050,044, which
primarily consisted of account payable. Warburg contributed $25,000,000 and
received preferred stock, with an 8% accrued dividend, convertible into 63.2% of
Gryphon's common stock.
Cheniere and Warburg also have the option, in connection with subsequent capital
calls made by Gryphon, to contribute up to an additional $75,000,000 to Gryphon,
proportionate to their respective ownership interests. Under the terms of the
agreement governing these additional contributions, in the event that either
Cheniere or Warburg elects not to participate in any additional contribution,
the other investor has the option to purchase the non-participating investor's
proportionate share. Assuming (i) that Gryphon makes subsequent capital calls
for an aggregate of $75,000,000, (ii) that Cheniere elects not to participate in
any of the capital calls and (iii) that Warburg elects to purchase all of
Cheniere's proportionate share, the Company's effective interest in Gryphon,
after giving effect to the conversion of Gryphon's preferred stock, will be
reduced to 12.7%. Cheniere accounted for the contribution of net assets at its
historical cost, whereby the net amount of such assets and liabilities less the
$2,000,000 in cash was reclassified to investment in affiliate. No gain or loss
was recognized at the time of contribution, primarily due to Cheniere's
commitment to provide additional funding described above and due to the
uncertainty of realization of the carrying value of the contributed unproved oil
and gas properties.
37
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Cheniere accounts for its investment in Gryphon using the equity method of
accounting. Cheniere does not participate in the day-to-day management of
Gryphon, does not exercise control over Gryphon and cannot effect a change in
the management of Gryphon. Cheniere's equity share of Gryphon's earnings
(losses) for the period from October 11, 2000 through December 31, 2000 was
$426,649, calculated by applying Cheniere's 100% common stock ownership interest
to Gryphon's net income of $19,003 and reducing such result for Gryphon's
preferred dividend arrearages ($445,652). At such time as Warburg converts its
preferred shares to common shares, Cheniere's equity share of Gryphon's earnings
(losses) will be calculated at 36.8% and will not be reduced by preferred
dividends. Gryphon's preferred stock is convertible at the option of the holder
at a rate of $100 per share of common stock at any time after the holders of a
majority of the preferred stock execute a written consent permitting a
conversion of the preferred stock or, if earlier, at any time after August 31,
2010. In the event the holders of a majority of the preferred stock vote to
convert all of their shares of preferred stock into common stock, all shares of
preferred stock shall automatically be converted, without further action by
Gryphon or its shareholders. In addition, Gryphon has the right, at its option,
to convert shares of preferred stock into common stock upon Gryphon's closing of
a firm commitment qualified public offering.
Summarized financial information relative to Gryphon is set forth below:
December 31,
2000
----------------
Current assets $ 24,041,892
Oil and gas properties, full cost method 18,196,153
Noncurrent cash deposits 2,607,648
Fixed assets 651,453
Current liabilities 11,124,538
Long-term liabilities --
Deferred tax liability 1,183,789
Year Ended
December 31,
2000
------------
Revenues $ --
Net income 19,003
Cheniere's equity in earnings (loss) from unconsolidated affiliate (426,649)
As of December 31, 2000 Cheniere's share of the underlying equity in the net
assets of Gryphon exceeded its investment balance by approximately $2.0 million.
Cheniere will amortize this basis difference over the estimated useful lives of
the assets contributed to Gryphon.
38
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
NOTE 7-NOTES PAYABLE
At December 31, 2000, Cheniere had no outstanding debt obligations. At December
31, 1999, Cheniere had outstanding short-term notes payable of $4,963,213. Three
financing facilities comprised the balance: platform financing of $3,090,643,
well services financing of $1,117,570 and December 1997 bridge financing notes
of $755,000. The terms of each of these facilities and of others that were
utilized within the three years ended December 31, 2000, are described in the
following paragraphs.
April 2000 - $2,000,000 Bridge Financing
In April 2000, the Company established a bridge financing facility which
provided for: borrowings of up to $2,000,000 bearing interest at a rate equal to
LIBOR plus 2%, a placement fee equal to 2% of the commitment amount, the
issuance of warrants to purchase 250,000 shares of common stock at an exercise
price of $4.00 per share on or before September 6, 2003, and conversion of the
notes payable into common stock, at Cheniere's election, at a price per share
equal to $2.00 per share. Cheniere borrowed an aggregate of $2,000,000 under the
facility during 2000. In September 2000, the Company repaid $500,000 in cash and
issued 250,000 shares to satisfy an additional $500,000. In December 2000,
Cheniere repaid the remaining balance of $1,000,000 plus accrued interest.
September 1999 - $3,100,000 Platform Financing
On September 1, 1999, Cheniere established a $3,100,000 financing facility to
fund a production platform and other exploration and development costs in the
West Cameron Block 49 area. Borrowings under the facility were repaid from
Cheniere's share of net cash flow from production through the West Cameron Block
49 platform. The note was secured by Cheniere's oil and gas properties and had a
maturity date of June 30, 2000. Financing costs included interest at 10% per
annum and a 5% net profit interest in the initial two wells producing through
the platform. At December 31, 1999, the outstanding balance under the facility
was $3,090,643. During 2000, the Company borrowed an additional $605,000 under
the same facility and repaid all principal and interest due under the facility.
December 1999 - $1,117,570 Well Services Financing
In December 1999, Cheniere entered into a financing agreement with a supplier of
well services to consolidate and convert trade accounts payable balances into a
short-term secured note payable. Interest was payable at 10% per annum. The note
was secured by Cheniere's oil and gas properties and matured on July 5, 2000. At
December 31, 1999, the outstanding balance was $1,117,570, which balance and all
related interest were repaid during 2000.
December 1997 - $4,000,000 Bridge Financing
In December 1997, Cheniere completed the private placement of a $4,000,000
bridge financing. The notes payable issued by Cheniere had an initial maturity
date of March 15, 1998, which was extended ultimately to March 15, 2000, when
the then-remaining balance was paid. In connection with the issuance of the
notes payable and with various extensions in the maturity dates, the Company has
issued 70,273 shares of common stock and warrants to purchase 925,809 shares of
common stock at prices ranging from $4.00 to $7.00 per share. The notes bore
interest at rates ranging from LIBOR plus 4% to LIBOR plus 6% (approximately
12.14% at December 31, 1999).
NOTE 8-INCOME TAXES
From its inception the Company has recorded losses for both financial reporting
purposes and for federal income tax reporting purposes. Accordingly, the Company
is not presently a taxpayer and has not recorded a provision for income taxes in
any of the periods presented in the accompanying financial statements.
At December 31, 2000, the Company had net operating loss (NOL) carryforwards for
tax reporting purposes of approximately $16,937,000. In accordance with SFAS No.
109, a valuation allowance equal to the net tax benefit for deferred taxes has
been established due to the uncertainty of realizing the benefit of such NOL
carryforwards.
39
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Deferred tax assets and liabilities reflect the net tax effect of temporary
differences between the carrying amount of assets and liabilities for financial
reporting purposes and amounts used for income tax purposes. Significant
components of the Company's deferred tax assets and liabilities at December 31,
2000 and 1999 are as follows:
December 31,
------------------------------------------------------------
2000 1999 1998
---------------- ---------------- ----------------
Deferred tax assets
NOL carryforwards $ 6,267,000 $ 4,400,000 $ 1,554,000
---------------- ---------------- ----------------
Deferred tax liabilities
Oil and gas properties and fixed assets 971,880 1,425,714 -
Investment in unconsolidated affiliate 1,642,160 - -
---------------- ---------------- ----------------
2,614,040 1,425,714 -
---------------- ---------------- ----------------
Net deferred tax assets 3,652,960 2,974,286 1,554,000
---------------- ---------------- ----------------
Less: valuation allowance (3,652,960) (2,974,286) (1,554,000)
---------------- ---------------- ----------------
$ - $ - $ -
================ ================ ================
NOL carryforwards expire starting in 2006 extending through 2020. NOLs incurred
prior to July 3, 1996 (approximately $747,000) are subject to per year
availability under Internal Revenue Code Section 382 change of ownership
limitations. Certain of the Company's NOLs incurred after July 3, 1996 are also
subject to an annual limitation of approximately $2,000,000 under Section 382.
The gross change in the valuation allowance for deferred tax assets increased
approximately $679,000, $1,420,000 and $557,000 during the years ended December
31, 2000, 1999 and 1998, respectively.
NOTE 9-WARRANTS
As of December 31, 2000, Cheniere has issued and outstanding 2,758,621 warrants
for the purchase of its common stock. The Company has reserved an equal number
of shares of common stock for issuance upon the exercise of its outstanding
warrants. Warrants issued by the Company do not confer upon the holders thereof
any voting or other rights of a stockholder of the Company. The Company grants
warrants in connection with certain of its debt or equity financings and as
compensation for services. In instances where warrants were granted in
connection with financings, the valuation of such warrants was calculated in
accordance with the provisions of APB Opinion No. 14, incorporating the
estimated fair market value of the stock at the time. Where warrants were issued
for services, fair value was calculated using the Black- Scholes pricing model.
The terms of warrants outstanding at December 31, 2000 range from two years to
five years, with a weighted average remaining life of 2.5 years at December 31,
2000. All outstanding warrants are fully exercisable. Prices at which the
warrants are exercisable range from $1.75 to $11.50 per share, with a weighted
average exercise price of $4.52 per share at December 31, 2000. Information
related to Cheniere's issuances of warrants is summarized in the following
table:
40
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
December 31,
--------------------------------------------
2000 1999 1998
------------- -------------- -------------
Outstanding at beginning of period 2,116,951 1,200,834 430,000
Warrants issued 1,291,462 941,117 773,959
Warrants exercised (234,375) (25,000)
Warrants canceled (415,417) -- (3,125)
---------- ---------- ----------
Outstanding at end of period 2,758,621 2,116,951 1,200,834
========== ========== ==========
Weighted average exercise price of warrants outstanding $ 4.52 $ 5.94 $ 6.81
========== ========== ==========
Weighted average remaining contractual life of warrants outstanding 2.5 years 3.0 years 3.3 years
The following table summarizes information about warrants outstanding at
December 31, 2000:
Weighted Average
Exercise Number Years Remaining
Prices Outstanding Contractual Life
----------------- -------------- ---------------------
$9.50-$11.50 25,000 3.7
$7.00-$8.00 313,542 2.9
$5.00-$6.00 794,384 1.9
$4.00 992,350 2.0
$3.00 258,345 3.0
$1.75 375,000 4.5
--------------
2,758,621
NOTE 10-STOCK-BASED COMPENSATION
In 1997 the Company established the Cheniere Energy, Inc. 1997 Stock Option Plan
(the Option Plan), which allows for the issuance of options to purchase up to
1,500,000 shares of Cheniere common stock. The Company has reserved 1,500,000
shares of common stock for issuance upon the exercise of options which have been
granted or which may be granted. The term of options granted under the Option
Plan is generally five years. Vesting varies, but generally occurs over three or
four years, in increments of 33% or 25%, respectively, on each anniversary of
the grant date.
41
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
A summary of the status of the Company's stock options as of December 31, 2000,
1999 and 1998 is presented below:
December 31,
--------------------------------------------
2000 1999 1998
------------ ------------ -----------
Outstanding at beginning of period 540,299 171,611 134,861
Options granted at an exercise price of $12.00 per share -- 8,750 33,750
Options granted at an exercise price of $6.00 per share 83,750 368,375 3,000
Options granted at an exercise price of $2.75 per share 450,875 -- --
Options granted at an exercise price of $1.94 per share 380,000 -- --
Options canceled (570,688) (8,437) --
-------- -------- --------
Outstanding at end of period 884,236 540,299 171,611
======== ======== ========
Exercisable at end of period 220,799 190,299 80,174
======== ======== ========
Weighted average exercise price of options outstanding $ 3.45 $ 6.32 $ 6.72
======== ======== ========
Weighted average exercise price of options exercisable $ 5.03 $ 6.56 $ 6.68
======== ======== ========
Weighted average fair value of options granted during the period $ 1.39 $ 3.40 $ 3.16
======== ======== ========
Weighted average remaining contractual life of options outstanding 4.3 years 4.7 years 3.4 years
42
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The following table summarizes information about fixed options outstanding at
December 31, 2000:
Options
Options Outstanding Exercisable
------------------------------------- --------------
Weighted Average
Exercise Number Years Remaining Number
Prices Outstanding Contractual Life Outstanding
--------------- -------------- --------------------- --------------
$ 12.00 17,500 2.8 17,500
$ 7.20 4,861 2.9 4,861
$ 6.00 228,750 3.5 107,813
$ 2.75 253,125 4.4 53,125
$ 1.94 380,000 4.9 37,500
--------- -------
884,236 220,799
========= =======
The fair value of options is calculated using the Black-Scholes option- pricing
model. Assumptions used in the pricing model and pro forma effects on the
Company's net losses had it adopted the optional recognition provisions of SFAS
No. 123 for the years ended December 31, 2000, 1999 and 1998 are summarized in
the following table. The effects of applying SFAS No. 123 in this pro forma
disclosure are not indicative of future amounts.
Year Ended December 31,
---------------------------------------------------
2000 1999 1998
--------------- ----------------- -----------------
Dividend yield 0.0% 0.0% 0.0%
Weighted average volatility 82.0% 124.0% 88.0%
Risk-free interest rate 5.8% 6.3% 4.6%
Expected lives of options 4.0 years 3.0 years 2.5 years
Net loss $ (780,980) $ (1,753,723) $ (1,637,844)
Net loss per share (both basic and diluted) $ (0.07) $ (0.27) $ (0.41)
Pro forma net loss $ (1,019,208) $ (3,184,723) $ (1,792,844)
Pro forma net loss per share (both basic and diluted) $ (0.09) $ (0.49) $ (0.45)
43
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
On December 11, 1998, the Company adjusted the exercise price from $12.00 to
$6.00 per share for the 143,750 options then issued and outstanding to
management and employees. On September 30, 1999, all options then outstanding to
management and employees were extended to September 30, 2004.
In June 1999, the Company issued 250,000 warrants to its president and chief
executive officer and 50,000 warrants to another member of its board of
directors, both of whom were instrumental in negotiating the Company's license
of 8,800 square miles of 3-D seismic data in the Gulf of Mexico. Warrants issued
in connection with this transaction are exercisable on or before the fifth
anniversary of the date the transaction closed at an exercise price of $6.00 per
share. The 250,000 warrants issued to Cheniere's president and chief executive
officer were canceled in October 2000, when he resigned from Cheniere to become
president and chief executive officer of Gryphon. An additional 250,000 warrants
were issued to Cheniere's new president and chief executive officer in October
2000, pursuant to the terms of his employment agreement. The fair value of these
warrants is included in the above pro forma net loss calculated under SFAS No.
123.
NOTE 11-RELATED PARTY TRANSACTIONS
Under the terms of the Contribution and Subscription Agreement dated October 11,
2000 by and among the Company, Gryphon and the other investors listed therein,
Gryphon provided office space to Cheniere at no cost from the closing date of
October 11, 2000 until Cheniere relocated in December 2000, and Cheniere is
providing accounting and cash management services to Gryphon without charge for
six months following the closing date. The values of the office space and the
accounting and cash management services offset and were not significant to the
Company.
Cheniere served as contract operator throughout 2000 for the well contributed to
Gryphon on which drilling was underway at the date of Gryphon's inception.
Cheniere received industry standard overhead reimbursements from all working
interest owners, including Gryphon, in accordance with the terms of the joint
interest operating agreement.
BSR Investments, Ltd., a major stockholder of the Company controlled by the
mother of Charif Souki, Chairman of Cheniere, purchased $2,000,000 of the notes
issued in the Company's $4,000,000 December 1997 Bridge Financing and pledged a
portion of its investment in Cheniere common stock to fund its participation. In
conjunction with the financing, BSR received warrants to purchase 41,667 shares
of the Company's common stock. On September 15, 1998, BSR received warrants to
purchase an additional 100,000 shares of common stock as consideration for
extending the maturity of the notes to that date. Also in September 1998, the
exercise price of the warrants held by BSR was reduced from $9.50 to $6.00 per
share as consideration to extend the maturity date of the notes to January 15,
1999. In March 1999, BSR exchanged notes payable of $2,000,000 for 694,445
shares of Cheniere common stock ($2.88 per share).
In May 1999, BSR purchased from another noteholder $240,000 in short-term notes
payable by Cheniere. In July 1999, the Company repaid $120,000 to BSR at the
time it repaid 50% of the outstanding balances on all of the notes issued in the
December 1997 Bridge Financing. On September 30, 1999, BSR exchanged its
remaining $120,000 note payable and $1,000 in accrued interest for 27,500 units
($4.40 per unit), each unit representing one share of common stock and one half
warrant to purchase a share of common stock at an exercise price of $6.00 per
share on or before September 30, 2002.
In conjunction with certain of the Company's private placements of equity,
placement fees have been paid to Investors Administration Services, Limited
(IAS), a company in which the brother of Charif Souki, Cheniere's chairman, is a
principal. Placement fees paid to IAS totaled $99,000 for 2000, $562,372 for
1999 and $138,000 for 1998. Such payments were recorded as offering costs and
reflected as a reduction of additional paid-in capital. In addition, in
connection with the sale of 2,620,758 units (of common stock and warrants),
Cheniere granted to IAS, or its assigns, warrants to purchase 161,250 shares of
common stock at an exercise price of $4.00 per share on or before December 30,
2002.
During June 1998, the Company received and repaid short-term advances from then
co-chairman of the board, William D. Forster, and members of his family or
entities under their control, totaling $592,000. Interest was paid at LIBOR plus
4% and totaled $1,622. In addition, non-interest bearing, short-term advances
totaling $105,000 were made to the Company by co-chairman Forster ($75,000) and
BSR ($30,000) in October and November 1998. Such advances were repaid by the
Company in October and November 1998.
44
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
NOTE 12-COMMITMENTS AND CONTINGENCIES
In November 2000, the Company entered into an office lease agreement with a term
which runs through March 31, 2003. Future minimum lease payments are $112,607,
$112,607 and $28,152 for the years ended December 31, 2001, 2002 and 2003,
respectively. Effective in October 2000, Cheniere assigned its rights and
obligations under its previous office lease agreement to Gryphon. Cheniere's
total rental expense for office space for the years ended December 31, 2000,
1999 and 1998 was $222,394, $229,381 and $42,741, respectively. Cheniere has no
other leasing commitments.
In June 1999, Cheniere entered into a master license agreement covering the
license of approximately 8,800 square miles of seismic data in the Gulf of
Mexico. In connection with the license agreement, the Company made a commitment
to reprocess certain of the seismic data and to pay a fee for such reprocessing
as the reprocessed data are delivered. In October 2000, Cheniere's rights and
obligations arising from this license agreement were assigned to Gryphon.
Related to the assignment of this license, Cheniere is obligated to pay a
transfer fee of up to $2,500,000, payable in ten installments of $250,000, which
will become payable after one month of production from each of ten separate
successful wells completed by Gryphon within the data set.
In June 2000, Cheniere entered into agreements whereby Cheniere acquired a
license to seismic data covering 1,900 square miles in the Gulf of Mexico in
exchange for its commitment to fund the reprocessing of the data. The Company
had a commitment to fund approximately $4,108,000 for the processing of such
data. As of December 31, 2000, the Company made payments of $500,000 with the
remainder of the commitment to be recorded as an obligation and paid as the work
is completed and the data delivered. The Company expects the data to be
delivered in 2001. In the event the reprocessing is not completed, the Company
would retain the data in the existing format and would not be required to pay
any additional amounts. In October 2000, Cheniere exercised its option to expand
the agreement to cover an additional 1,900 square miles.
In November 2000, Cheniere acquired from another company a license to seismic
data covering an additional 3,000 square miles in the Gulf of Mexico in exchange
for its commitment to fund the reprocessing of the data. The Company had a
commitment to fund approximately $4,324,000 for the processing of such data. As
of December 31, 2000, the Company made payments of $150,000 with the remainder
of the commitment to be recorded as an obligation and paid as the work is
completed and the data delivered. The Company expects the data to be delivered
in 2001. In the event the reprocessing is not completed, the Company would
retain the data in the existing format and would not be required to pay any
additional amounts.
Under the terms of the Contribution and Subscription Agreement dated October 11,
2000 by and among the Company, Gryphon and the other investors listed therein,
Cheniere and the other investors have committed under certain circumstances to
contribute their pro rata shares of as much as an additional $75,000,000 to
Gryphon. The amount of such contributions, if any, will depend on the future
cash requirements of Gryphon. Cheniere may choose to make such contributions to
maintain its 36.8% voting ownership interest in Gryphon or it may choose to
contribute a lesser amount or zero, in which case its ownership interest in
Gryphon would be reduced.
NOTE 13-LIQUIDITY
The recoverability of the Company's unevaluated oil and gas properties is
dependent on future events, including obtaining adequate financing for its
exploration and development program, the successful reprocessing of the 3D
seismic data in the Offshore Texas Project Area, the successful completion of
its planned drilling program, and the achievement of a level of operating
revenues that is sufficient to support the Company's cost structure. At various
times during the life of the Company to date, it has been necessary for the
Company to raise additional capital through private placements of debt or equity
financing. When such a need has arisen, the Company has met it successfully. It
is management's belief that it will continue to be able to meet its needs for
additional capital as such needs arise in the future.
Cheniere's needs for additional financing include the following:
. Additional capital may be required to pay for Cheniere's share of costs
relating to the drilling of prospects and development of those that are
successful, to exercise lease options, and to acquire additional oil and gas
leases. The total amount of the Company's capital needs will be determined in
part by the number of prospects generated within its exploration program and by
the working interest that the Company retains in those prospects.
. The Company will need funds for the payment of approximately $8,000,000
related to future deliveries of reprocessed seismic data through December 2001.
(Note 12)
45
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
. The Company may need capital to fund its pro-rata share of the capital calls
by Gryphon that are approved by Gryphon's Board of Directors. (Note 12)
. The Company will need funds for the payment of any transfer fee related to the
assignment to Gryphon of its seismic license over the Offshore Louisiana Project
Area. (Note 12)
. Should the Company choose to make an acquisition of producing oil and gas
properties, it is likely that such an acquisition would require that some
portion of the purchase price be paid in cash, and thus would create the need
for additional capital.
Additional capital could be obtained from a combination of funding sources.
These potential funding sources include:
. cash flow from operating activities,
. borrowings from financial institutions,
. debt offerings, which would increase the Company's leverage and add to its
need for cash to service such debt,
. additional offerings of the Company's equity securities, which would cause
dilution of its common stock,
. sales of portions of its working interest in the prospects within its
exploration program, which would reduce future revenues from its exploration
program,
. sale to an industry partner of a participation in the Company's exploration
program, including sale of a license to the approximate 6,800 square miles of
seismic data in the Offshore Texas Project Area, which would reduce future
revenues from its exploration program, and
. sale of all or a portion of the Company's producing oil and gas properties,
which would reduce future revenues.
Cheniere's ability to raise additional capital will depend on the results of its
operations and the status of various capital and industry markets at the time
such additional capital is sought. Accordingly, there can be no assurances that
capital will be available to the Company from any source or that, if available,
it will be on terms acceptable to the Company.
NOTE 14-SUPPLEMENTAL DISCLOSURES OF NON-CASH TRANSACTIONS
In conjunction with its December 1997 Bridge Financing, the Company issued at
closing 25,000 shares of common stock (valued at $237,500) and upon extension of
the maturity date 12,500 shares of common stock (valued at $33,500), which were
recorded as debt issuance costs. In the same financing, the Company issued
warrants to purchase 333,334 shares of its common stock (valued at $101,000) and
warrants to purchase 496,875 shares of its common stock (valued at $315,833)
related to extensions of the maturity dates. In conjunction with a short-term
bridge financing in June 1998, the Company issued warrants to purchase 20,834
shares of common stock (valued at $3,661). The value of the warrants related to
these financings was recorded as debt issue costs and the amortization of such
warrant costs was included in interest expense, which was capitalized as a cost
of oil and gas properties.
In 1998, the Company issued 17,500 shares of common stock (valued at $98,000) in
settlement of invoices for previously rendered legal services.
In 1999, the Company issued 703,132 shares of common stock in exchange for
$2,025,020 in notes payable and 56,250 shares of common stock in exchange for
$75,000 in notes payable. The Company also issued 36,047 units (each unit
representing one share of common stock and one half of a warrant to purchase one
share of common stock) in exchange for notes payable and accrued interest
totaling $158,608. In March 1999, the Company adjusted the exercise price for
certain warrants (valued at $35,702) in connection with the extension of the
maturity dates of notes payable. In the fourth quarter of 1999, the Company
issued 32,773 shares of common stock and warrants to purchase 95,600 shares of
common stock (collectively valued at $98,197) in connection with the extension
of maturity dates of notes payable. The Company issued 514,366 shares of common
stock to purchase oil and gas services and seismic data valued at $2,828,210. In
October 1999, the Company issued warrants to purchase 50,000 shares of common
stock (valued at $200,000) in payment for investor relations consulting services
and recorded within general and administrative expenses over the six-
46
CHENIERE ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
month term of the consulting agreement. The Company issued 37,500 shares (valued
at $37,500) in connection with the employment of one of its executives. The
Company issued a short-term note payable for oil and gas services valued at
$1,117,570.
In 2000, Cheniere issued 16,667 shares of common stock in exchange for seismic
data reprocessing services valued at $50,000. The Company issued 50,000 shares
of common stock as a price adjustment to shares issued in 1999 for oil and gas
drilling services. Cheniere issued warrants to purchase 25,000 shares of common
stock (valued at $30,300) as a placement fee in connection with the sale of
securities. The Company issued warrants to purchase 250,000 shares of common
stock (valued at $528,000) in connection with the establishment of a bridge
financing facility. Cheniere issued 250,000 shares of common stock in
satisfaction of $500,000 in short- term notes payable issued under the bridge
financing facility. Cheniere also issued warrants to purchase 250,000 shares of
common stock to its president and chief executive officer in October 2000,
pursuant to his employment agreement. The Company issued its financial advisers
warrants to purchase 125,000 shares of common stock, valued at $164,500, as
consideration for assistance in the capitalization of Gryphon.
The values of securities issued by the Company in connection with the
transactions described above are based on third party arms-length negotiated
prices.
In connection with the Gryphon transaction, Cheniere contributed to Gryphon
certain assets and liabilities with a net book value of $7,065,919 for its 36.8%
ownership interest in the company.
NOTE 15-SUBSEQUENT EVENTS
In February 2001, the Company completed a private placement of units (common
stock and warrants) at a price of $2.00 per unit, generating net proceeds of
$500,000. In connection with the offering, the Company issued 250,000 shares of
common stock and 41,667 warrants to purchase common stock exercisable at a price
of $3.00 per share on or before December 31, 2003.
47
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
OIL AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
COSTS INCURRED IN OIL AND GAS PRODUCING ACTIVITIES
Presented below are costs incurred in oil and gas property acquisition,
exploration and development activities:
Years Ended December 31,
---------------------------------------------------------
2000 1999 1998
----------------- ----------------- ---------------
Acquisition of properties:
Proved properties $ -- $ 1,364,809 $ --
Unproved properties 6,603,296 648,498 3,466,371
Exploration costs -- 7,675,809 --
Development costs 673,136 1,618,609 --
----------- ----------- -----------
Subtotal 7,276,432 11,307,725 3,466,371
Amounts contributed to
unconsolidated affiliate (9,379,534) -- --
----------- ----------- -----------
Total $(2,103,102) $11,307,725 $ 3,466,371
=========== =========== ===========
Included in the above amounts for the years ended December 31, 2000, 1999 and
1998 were $1,897,454, $1,375,262 and $1,502,595, respectively, of capitalized
general and administrative expenses and capitalized interest expense directly
related to property acquisition, exploration and development.
48
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
OIL AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
Capitalized Costs Related to Oil and Gas Producing Activities
The following table presents total capitalized costs of proved and unproved
properties and accumulated depreciation, depletion and amortization related to
oil and gas producing operations:
December 31,
---------------------------------------------------------
2000 1999 1998
----------------- ----------------- ----------------
Proved properties $ 10,951,317 $ 10,659,227 $ --
Unproved properties 18,253,731 20,648,923 20,000,425
------------ ------------ ------------
29,205,048 31,308,150 20,000,425
Accumulated depreciation, depletion and amortization (4,223,704) (1,200,186) $ --
------------ ------------ ------------
$ 24,981,344 $ 30,107,964 $ 20,000,425
============ ============ ============
RESULTS OF OPERATIONS FROM OIL AND GAS PRODUCING ACTIVITIES
The results of operations from oil and gas producing activities are as follows:
Year ended December 31,
----------------------------------
2000 1999
--------------- ----------------
Revenues $ 5,320,432 $ 1,614,055
Production costs (388,637) (128,859)
Depreciation, depletion and amortization (3,023,518) (1,200,186)
Income tax benefit (expense) - -
--------------- ----------------
Results of operations from oil and gas producing activities
(excluding corporate overhead and interest costs) $ 1,908,277 $ 285,010
=============== ================
49
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
OIL AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
RESERVE QUANTITIES
Estimates of proved reserves of Cheniere and the related standardized measure of
discounted future net cash flow information are based on the reports generated
by the Company's independent petroleum engineers in accordance with the rules
and regulations of the SEC. The independent engineers' estimates were based upon
a review of production histories and other geologic, economic, ownership and
engineering data provided by the Company. These estimates represent the
Company's interest in the reserves associated with its properties. All of the
Company's oil and gas reserves are located within the United States or its
territorial waters.
The Company's estimates of its proved reserves and proved developed reserves of
oil and gas as of December 31, 2000 and 1999 and the changes in its proved
reserves are as follows:
2000 1999
--------------------------- --------------------------
Oil Gas Oil Gas
(Bbls) (Mcf) (Bbls) (Mcf)
---------- -------------- ---------- --------------
Proved reserves:
Beginning of year - consolidated 27,816 5,796,000 - -
Revisions of prior estimates (7,200) (354,103) - -
Production (3,703) (1,459,897) (2,975) (633,432)
Extensions, discoveries and other additions 2,961 586,000 30,791 6,429,432
---------- -------------- ---------- --------------
End of year - consolidated 19,874 4,568,000 27,816 5,796,000
Proportional Interest in proved reserves of
unconsolidated affiliate - end of year (1) 2,640 1,674,000 - -
---------- -------------- ---------- --------------
End of year - total 22,514 6,242,000 27,816 5,796,000
========== ============== ========== ==============
Proved developed reserves:
Beginning of year 27,816 5,796,000 - -
========== ============== ========== ==============
End of year - consolidated 16,913 3,982,000 27,816 5,796,000
Interest in proved developed reserves of
unconsolidated affiliate - end of year (1) 2,640 1,674,000 - -
---------- -------------- ---------- --------------
End of year - total 19,553 5,656,000 27,816 5,796,000
========== ============== ========== ==============
50
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
OIL AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
(1) Represents Cheniere's proportional share, based on its 100% common stock
ownership, of the proved reserves and proved developed reserves of Gryphon. Such
proportional share of Gryphon reserves will be reduced to 36.8% upon the
conversion of Gryphon's preferred shares.
There are numerous uncertainties inherent in estimating quantities of proved
reserves and in projecting future rates of production and future amounts and
timing of development expenditures, including many factors beyond the control of
the Company. Reserve engineering is a subjective process of estimating
underground accumulations of crude oil and natural gas that cannot be measured
in an exact manner, and the accuracy of any reserve estimate is a function of
the quality of available data and of engineering and geological interpretation
and judgment. Estimates of proved undeveloped reserves are inherently less
certain than estimates of proved developed reserves. The quantities of oil and
gas that are ultimately recovered, production and operating costs, the amount
and timing of future development expenditures, geologic success and future oil
and gas sales prices may all differ from those assumed in these estimates. In
addition, the Company's reserves may be subject to downward or upward revision
based upon production history, purchases or sales of properties, results of
future development, prevailing oil and gas prices and other factors.
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
The standardized measure of discounted future net cash flows was calculated by
applying year-end prices to estimated future production, less future
expenditures (based on year-end costs) to be incurred in developing and
producing the Company's proved reserves and the estimated effect of future
income taxes based on the current tax law. The resulting future net cash flows
were discounted using a rate of 10% per annum.
The standardized measure of discounted future net cash flow amounts contained in
the following tabulation does not purport to represent the fair market value of
oil and gas properties. No value has been given to unproved properties. There
are significant uncertainties inherent in estimating quantities of proved
reserves and in projecting rates of production and the timing and amount of
future costs. Future realization of oil and gas prices over the remaining
reserve lives may vary significantly from current prices. In addition, the
method of valuation utilized, based on year-end prices and costs and the use of
a 10% discount rate, is not necessarily appropriate for determining fair value.
The standardized measure of discounted future net cash flows relating to proved
oil and gas reserves is as follows:
2000 1999
----------------- ---------------
Future gross revenues $ 48,989,932 $ 13,651,636
Less - future costs:
Production (5,853,817) (2,050,892)
Development and dismantlement (2,823,300) (1,516,500)
----------------- ---------------
Future net cash flows before income taxes 40,312,815 10,084,244
Less - 10% annual discount for estimated timing of cash flows (14,632,097) (2,514,115)
----------------- ---------------
Present value of future net cash flows before income taxes 25,680,718 7,570,129
Less - present value of future income taxes (5,062,716) -
----------------- ---------------
Standardized measure of discounted future net cash flows $ 20,618,002 $ 7,570,129
================= ===============
51
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
OIL AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
The following table summarizes the principal sources of change in the
standardized measure of discounted future net cash flows:
Year Ended December 31,
-------------------------------
2000 1999
------------- --------------
Standardized measure - beginning of period $ 7,570,129 $ -
Sales of oil and gas produced, net of production costs (4,931,795) (1,485,196)
Extensions, discoveries and other additions 3,537,975 9,055,325
Revisions to previous quantity estimates, timing and other (2,349,930) -
Net changes in prices and production costs 20,424,190 -
Development costs incurred 673,136 -
Net changes in income taxes (5,062,716) -
Accretion of discount 757,013 -
---------------- --------------
Standardized measure - end of period - consolidated $ 20,618,002 $ 7,570,129
Standardized measure - end of period - proportional interest in
reserves of unconsolidated affiliate (1) 9,138,920 -
---------------- --------------
Standardized measure - end of period - total $ 29,756,922 $ 7,570,129
================ ==============
Current prices at year-end, used in standardized measure
Oil (per barrel) $ 29.72 $ 25.47
Gas (per mcf) 10.71 2.34
52
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
OIL AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
(1) Represents Cheniere's proportional share, based on its 100% common stock
ownership, of the standardized measure of Gryphon's proved oil and gas reserves.
Such proportional share of Gryphon's standardized measure will be reduced to
36.8% upon the conversion of Gryphon's preferred shares.
(2) The Company may receive amounts different than those incorporated into the
standardized measure of discounted cash flow for a number of reasons, including
changes in prices. Therefore, the present value shown above should not be
construed as the current market value of the estimated oil and gas reserves
attributable to the Company's properties.
53
CHENIERE ENERGY, INC. AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
SUMMARIZED QUARTERLY FINANCIAL DATA
(unaudited)
First Second Third Fourth
Quarter Quarter Quarter Quarter Year
--------------- -------------- ------------- -------------- --------------
Year ended December 31, 2000:
Revenues (1) $ 1,173,605 $1,731,078 $1,198,052 $1,217,697 $ 5,320,432
Gross profit (2) 165,923 546,680 176,474 671,335 1,560,412
Income (loss) from operations (311,086) 353,925 (86,036) (335,050) (378,247)
Net income (loss) (302,377) 358,135 (81,131) (755,607) (780,980)
Net loss per share - basic and diluted $ (0.03) $ 0.03 $ (0.01) $ (0.07) $ (0.07)
Year ended December 31, 1999:
Revenues $ - $ - $ 421,268 $1,192,787 $ 1,614,055
Gross profit (2) (10,344) (10,982) 134,147 10,731 123,552
Loss from operations (334,043) (360,139) (347,522) (743,549) (1,785,253)
Net loss (329,105) (354,885) (333,999) (735,735) (1,753,724)
Net loss per share - basic and diluted $ (0.07) $ (0.06) $ (0.05) $ (0.09) $ (0.27)
(1) Revenues for the first three quarters of 2000 have been revised by $230,000,
$373,333 and $373,334 to present management fees as a reduction of general and
administrative expenses instead of as revenues as reported in the quarterly
financial statements. These reclassifications had no effect on net income.
(2) Revenues less operating expenses other than general and administrative.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
54
PART III
In accordance with paragraph (3) of General Instruction G to form 10-K, Part III
of this Report is omitted because the Company will file with the Securities and
Exchange Commission not later than 120 days after the end of the fiscal year
ended December 31, 2000 a definitive proxy statement pursuant to Regulation 14A
involving the election of directors, which proxy statement is incorporated
herein by reference (with the exception of certain portions noted therein that
are not so incorporated by reference).
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) Financial Statements, Schedules and Exhibits
(1) Financial Statements - Cheniere Energy, Inc and Subsidiaries
Report of Independent Accountants.................................. 28
Consolidated Balance Sheet......................................... 29
Consolidated Statement of Operations............................... 30
Consolidated Statement of Stockholders' Equity..................... 31
Consolidated Statement of Cash Flows............................... 32
Notes to Consolidated Financial Statements......................... 33
Supplemental Information to the Consolidated Financial Statements.. 48
(2) Financial Statement Schedule
All consolidated financial statement schedules have been omitted because they
are not required, are not applicable, or the required information has been
included elsewhere within this Form 10-K/A.
The financial statements of Gryphon Exploration Company, for which Cheniere uses
the equity method of accounting have been filed as part of this report on Form
10-K/A. (See Item 14 (d).)
(3) Exhibits
Exhibit No. Description
- ---------- -----------
3.1 Amended and Restated Certificate of Incorporation of Cheniere
Energy, Inc. (Cheniere) (Incorporated by reference to Exhibit 3.1
of the Company's Quarterly Report on Form 10-Q for the quarter
ended June 30, 1999 (File No. 0-9092))
3.2 Certificate of Amendment to the Amended and Restated Certificate of
Incorporation of Cheniere (Incorporated by reference to Exhibit 3.2
of the Company's Quarterly Report on Form 10-Q for the quarter
ended June 30, 1999 (File No. 0-9092))
3.3 By-laws of Cheniere as amended through April 7, 1997 (Incorporated
by reference to Exhibit 3.2 of the Company's Annual Report on Form
10-K for the year ended December 31, 1998 (File No. 0-9092))
4.1 Specimen Common Stock Certificate of Cheniere (Incorporated by
reference to Exhibit 4.1 of the Company's Registration Statement on
Form S-1 filed on August 27, 1996 (File No. 333-10905))
55
10.1 Exploration Agreement between FX Energy, Inc. (now known as
Cheniere Energy Operating Co., Inc. (Cheniere Operating)) and
Zydeco Exploration, Inc. (Zydeco) (Incorporated by reference to
Exhibit 10.1 of the Company's Registration Statement under the
Securities Act of 1933 on Form S-1 filed on August 27, 1996 (File
No. 333-10905))
10.2 First Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.2 of the Company's Registration Statement
on Form S-1 filed on August 27, 1996 (File No. 333-10905))
10.3 Second Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.3 of the Company's Registration Statement
on Form S-1 filed on August 27, 1996 (File No. 333-10905))
10.4 Third Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.4 of the Annual Report on Form 10-K for the
year ended August 31, 1996 (File No. 2-63115))
10.5 Form of Warrant Agreement between Cheniere and each of C.M. Blair,
W.M. Foster & Co., Inc. and Redliw Corp. (Incorporated by reference
to Exhibit 10.8 of the Company's Registration Statement on Form S-1
filed on August 27, 1996 (File No. 333-10905))
10.6 Fourth Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.12 of the Company's Registration Statement
on Form S-1 filed on March 17, 1997 (File No. 333-23421))
10.7 Fifth Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.18 of the Annual Report on Form 10-K for
the year ended August 31, 1997 (File No. 0-9092))
10.8 Sixth Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.19 of the Annual Report on Form 10-K for
the year ended August 31, 1997 (File No. 0-9092))
10.9 Seventh Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.23 of the Annual Report on Form 10-K for
the year ended August 31, 1997 (File No. 0-9092))
10.10 Cheniere Energy, Inc. 1997 Stock Option Plan (Incorporated by
reference to Exhibit 10.25 of the Quarterly on Form 10-Q for the
quarter ended November 31, 1997 (File No. 0-9092))
10.11 Eighth Amendment to the Exploration Agreement between FX Energy,
Inc. (now known as Cheniere Operating) and Zydeco (Incorporated by
reference to Exhibit 10.26 of the Transition Report on Form 10-K
for the period from September 1, 1997 to December 31, 1997 (File
No. 0-9092))
10.12 Form of Securities Purchase Agreement dated December 15, 1997
(Incorporated by reference to Exhibit 10.27 of the Transition
Report on Form 10-K for the period from September 1, 1997 to
December 31, 1997 (File No. 0-9092))
56
10.13 Form of First Amendment to Securities Purchase Agreement dated
December 15, 1997 (Incorporated by reference to Exhibit 10.28 of
the Transition Report on Form 10-K for the period from September 1,
1997 to December 31, 1997 (File No. 0-9092))
10.14 Securities Purchase Agreement among Cheniere, Arabella S.A., Alba
Limited and Scorpion Energy Partners dated December 15, 1997
(Incorporated by reference to Exhibit 10.29 of the Transition
Report on Form 10-K for the period from September 1, 1997 to
December 31, 1997 (File No. 0-9092))
10.15 Letter Agreement between Cheniere and Zydeco dated December 31,
1997 (Incorporated by reference to Exhibit 10.30 of the Transition
Report on Form 10-K for the period from September 1, 1997 to
December 31, 1997 (File No. 0-9092))
10.16 Services Agreement dated October 1, 1998 between Cheniere and
Charif Souki (Incorporated by reference to Exhibit 10.22 of the
Annual Report on Form 10-K for the year ended December 31, 1998
(File No. 0-9092))
10.17 Form of Second Amendment to Securities Purchase Agreement dated
December 15, 1997 (Incorporated by reference to Exhibit 10.23 of
the Annual Report on Form 10-K for the year ended December 31, 1998
(File No. 0-9092))
10.18 Form of Third Amendment to Securities Purchase Agreement dated
December 15, 1997 (Incorporated by reference to Exhibit 10.24 of
the Annual Report on Form 10-K for the year ended December 31, 1998
(File No. 0-9092))
10.19 Form of Fourth Amendment to Securities Purchase Agreement dated
December 15, 1997 (Incorporated by reference to Exhibit 10.25 of
the Annual Report on Form 10-K for the year ended December 31, 1998
(File No. 0-9092))
10.20 Form of Fifth Amendment to Securities Purchase Agreement dated
December 15, 1997 (Incorporated by reference to Exhibit 10.26 of
the Annual Report on Form 10-K for the year ended December 31, 1998
(File No. 0-9092))
10.21 Exchange Agreement between Cheniere and BSR Investments, Ltd.
(Incorporated by reference to Exhibit 10.27 of the Annual Report on
Form 10-K for the year ended December 31, 1998 (File No. 0-9092))
10.22 Master License Agreement dated June 9, 1999 between Fairfield
Industries Incorporated and Cheniere. Certain information in this
exhibit has been omitted and filed separately with the Commission.
Confidential treatment has been requested with respect to the
omitted portions. (Incorporated by reference to Exhibit 10.28 of
the Quarterly Report on Form 10-Q for the quarter ended June 30,
1999 (File No. 0-9092))
10.23 Supplement Agreement No. 1 to Master License Agreement dated
June 9, 1999 between Fairfield Industries Incorporated and
Cheniere. Certain information in this exhibit has been omitted and
filed separately with the Commission. Confidential treatment has
been requested with respect to the omitted portions. (Incorporated
by reference to Exhibit 10.29 of the Quarterly Report on Form 10-Q
for the quarter ended June 30, 1999 (File No. 0-9092))
57
10.24 Credit Agreement between Cheniere as Borrower and EnCap Energy
Capital Fund III, L.P. as Lender for $3,100,000 dated as of
September 1, 1999 (Incorporated by reference to Exhibit 10.30 of
the Quarterly Report on Form 10-Q for the quarter ended September
30, 1999 (File No. 0-9092))
10.25 Conveyance of Net Profits Overriding Royalty Interest from and by
Cheniere Energy, Inc. to and in favor of EnCap Energy Capital Fund
III, L.P. dated as of September 1, 1999 (Incorporated by reference
to Exhibit 10.31 of the Quarterly Report on Form 10-Q for the
quarter ended September 30, 1999 (File No. 0-9092))
10.26 First Amendment to Cheniere Energy, Inc. 1997 Stock Option Plan.
(Incorporated by reference to Exhibit 10.26 of the Annual Report on
Form 10-K for the year ended December 31, 1999 (File No. 0-9092))
10.27 Exploration Agreement dated as of March 31, 2000 between Cheniere
and Samson Offshore Company. Certain information in this exhibit
has been omitted and filed separately with the Commission.
Confidential treatment has been requested with respect to the
omitted portions. (Incorporated by reference to Exhibit 10.28 of
the Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.28 First Amendment to Credit Agreement between Cheniere and EnCap
Energy Capital Fund III, L.P. dated December 31, 1999.
(Incorporated by reference to Exhibit 10.29 of the Annual Report on
Form 10-K for the year ended December 31, 1999 (File No. 0-9092))
10.29 Three Party Agreement dated January 4, 2000 between Cheniere, EnCap
Energy Capital Fund III, L.P., and Schlumberger Technology
Corporation. (Incorporated by reference to Exhibit 10.30 of the
Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.30 Subordination Agreement dated January 4, 2000 between Cheniere,
EnCap Energy Capital Fund III, L.P., and Schlumberger Technology
Corporation. (Incorporated by reference to Exhibit 10.31 of the
Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.31 Debt Restructure Agreement dated January 4, 2000 between Cheniere
and Schlumberger Technology Corporation. (Incorporated by reference
to Exhibit 10.32 of the Annual Report on Form 10-K for the year
ended December 31, 1999 (File No. 0-9092))
10.32 Second Amendment to Credit Agreement between Cheniere and EnCap
Energy Capital Fund III, L.P. dated February 29, 2000.
(Incorporated by reference to Exhibit 10.33 of the Annual Report on
Form 10-K for the year ended December 31, 1999 (File No. 0-9092))
10.33 Form of Sixth Amendment to Securities Purchase Agreement dated
December 15, 1997. (Incorporated by reference to Exhibit 10.34 of
the Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.34 Form of Seventh Amendment to Securities Purchase Agreement dated
December 15, 1997. (Incorporated by reference to Exhibit 10.35 of
the Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
58
10.35 Form of Eighth Amendment to Securities Purchase Agreement dated
December 15, 1997. (Incorporated by reference to Exhibit 10.36 of
the Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.36 Form of Ninth Amendment to Securities Purchase Agreement dated
December 15, 1997. (Incorporated by reference to Exhibit 10.37 of
the Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.37 Form of Tenth Amendment to Securities Purchase Agreement dated
December 15, 1997. (Incorporated by reference to Exhibit 10.38 of
the Annual Report on Form 10-K for the year ended December 31, 1999
(File No. 0-9092))
10.38 Seismic Data Purchase Agreement dated June 21, 2000 between Seitel
Data and Cheniere. (Incorporated by reference to Exhibit 10.39 of
the Quarterly Report on Form 10-Q for the quarter ended June 30,
2000 (File No. 0-9092))
10.39 Contribution and Subscription Agreement dated October 11, 2000, by
and among the Company, Gryphon Exploration Company and the other
investors listed therein. (Incorporated by reference to Exhibit
10.1 of the Company's Current Report on Form 8-K filed on
October 20, 2000)(File No. 0-9092))
10.40 Stockholders Agreement dated October 11, 2000. (Incorporated by
reference to Exhibit 10.2 of the Company's Current Report on Form
8-K filed on October 20, 2000 (File No. 0-9092))
10.41 Certificate of Designations, Preferences and Rights of Series A
Convertible Preferred Stock of Gryphon Exploration Company.
(Incorporated by reference to Exhibit 10.3 of the Company's Current
Report on Form 8-K filed on October 20, 2000 (File No. 0-9092))
21.1 Subsidiaries of Cheniere Energy, Inc. (Incorporated by reference to
Exhibit 21.1 of the Annual Report on Form 10-K filed on October 14,
1997 (File No. 0-9092))
23.1 Consent of PricewaterhouseCoopers LLP
(b) Reports On Form 8-K
. The Company filed a Current Report on Form 8-K on October 20, 2000 (File No.
0-9092) to report (i) the closing of a $25,000,000 agreement with Warburg,
Pincus Equity Partners, L.P., a global private equity fund based in New York, to
fund its exploration program on the Louisiana Data Set through a newly formed
affiliate Gryphon Exploration Company; (ii) the election of Charles M. Reimer as
President and Chief Executive Officer of the Company; and (iii) the approval of
the stockholders of the four-for-one reverse stock split at a special meeting of
the stockholders.
The Company filed a Current Report on Form 8-K on December 15, 2000 to report
that the Nasdaq Listing Qualifications Panel had notified the Company that its
common stock had been delisted from the Nasdaq SmallCap Market effective
December 14, 2000, and that its common stock would trade on the OTC Bulletin
Board effective December 14, 2000.
(c) Not applicable.
(d) Gryphon Exploration Company Financial Statements, for which Cheniere uses
the equity method of accounting, are filed as a part of this report on page
61.
59
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, INC.
By: /s/ DON A. TURKLESON
----------------------
Don A. Turkleson
Vice President, Chief Financial
Officer, Secretary and Treasurer
Date: November 29, 2001
60
INDEX TO FINANCIAL STATEMENTS
GRYPHON EXPLORATION COMPANY
Report of Independent Accountants.................. 62
Balance Sheet...................................... 63
Statement of Operations............................ 64
Statement of Stockholders' Equity.................. 65
Statement of Cash Flows............................ 66
Notes to Financial Statements...................... 67
Supplemental Information to Financial Statements... 74
61
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Stockholders of Gryphon Exploration Company
In our opinion, the accompanying balance sheet and the related statements of
operations, stockholders' equity and cash flows present fairly, in all material
respects, the financial position of Gryphon Exploration Company at December 31,
2000, and the results of its operations and its cash flows for the period from
inception (October 11, 2000 through December 31, 2000 in conformity with
accounting principles generally accepted in the United States of America. These
financial statements are the responsibility of the Company's management; our
responsibility is to express an opinion on these financial statements based on
our audit. We conducted our audit of these statements in accordance with
auditing standards generally accepted in the United States of America, which
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, assessing the accounting principles
used and significant estimates made by management, and evaluating the overall
financial statement presentation. We believe that our audit provides a
reasonable basis for our opinion.
PRICEWATERHOUSECOOPERS LLP
Houston, Texas
March 30, 2001
62
GRYPHON EXPLORATION COMPANY
BALANCE SHEET
December 31,
ASSETS 2000
-----------------
CURRENT ASSETS
Cash and Short-Term Investments $13,951,602
Restricted Cash Deposits 7,172,149
Receivables from Joint Interest Owners 1,695,000
Prepaid Expenses 1,223,141
----------------
Total Current Assets 24,041,892
OIL AND GAS PROPERTIES, full cost method
Proved Properties, net 2,727,143
Unproved Properties, not subject to amortization 15,469,010
----------------
Total Oil and Gas Properties 18,196,153
NONCURRENT RESTRICTED CASH DEPOSITS 2,607,648
FIXED ASSETS, net 651,453
----------------
Total Assets $45,497,146
================
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts Payable
Trade Accounts $ 3,397,326
Advances from Joint Interest Owners 7,172,149
Other 555,063
----------------
Total Current Liabilities 11,124,538
----------------
DEFERRED TAX LIABILITY 1,183,789
----------------
COMMITMENTS AND CONTINGENCIES (NOTE 10)
STOCKHOLDERS' EQUITY
Common Stock, $.01 par value
Authorized: 4,000,000 shares; Issued and Outstanding: 145,600 shares 1,456
Preferred Stock, $.01 par value
Authorized: 100,000 shares; Issued and Outstanding: 25,000 shares 250
Additional Paid-in-Capital 33,168,110
Retained Earnings 19,003
----------------
Total Stockholders' Equity 33,188,819
----------------
Total Liabilities and Stockholders' Equity $45,497,146
================
The accompanying notes are an integral part of the financial statements.
63
GRYPHON EXPLORATION COMPANY
STATEMENT OF OPERATIONS
Inception
(October 11, 2000)
Through
December 31, 2000
-------------------
Revenues $ --
---------
Operating Costs and Expenses
Depreciation, Depletion and Amortization 112,503
General and Administrative Expenses 119,165
---------
Total Operating Costs and Expenses 231,668
---------
Loss from Operations Before Interest Income and Income Taxes (231,668)
Interest Income 260,460
---------
Income From Operations Before Income Taxes 28,792
Provision for Income Taxes (9,789)
---------
Net Income $ 19,003
=========
The accompanying notes are an integral part of the financial statements.
64
GRYPHON EXPLORATION COMPANY
STATEMENT OF STOCKHOLDERS' EQUITY
Common Stock Preferred Stock Additional Total
------------------------ ----------------------- Paid-In Retained Stockholders'
Shares Amount Shares Amount Capital Earnings Equity
------------ ----------- ------------ ---------- --------------- ------------- ------------------
Balance - Date of Inception
(October 11, 2000) - $ - - $ - $ - $ - $ -
Issuance of Common Stock 145,600 1,456 9,064,463 - 9,065,919
Issuance of Preferred Stock 25,000 250 24,999,750 25,000,000
Expenses Related to Issuance - - - - (896,103) - (896,103)
Net Income - - - - - 19,003 19,003
------------ ----------- ------------ ---------- --------------- ------------- --------------
Balance - December 31, 2000 145,600 $ $1,456 25,000 $ 250 $ 33,168,110 $ 19,003 $ $33,188,819
============ =========== ============ ========== =============== ============= ==============
The accompanying notes are an integral part of the financial statements.
65
GRYPHON EXPLORATION COMPANY
STATEMENT OF CASH FLOWS
Inception
(October 11, 2000)
Through
December 31, 2000
----------------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Income $ 19,003
Adjustments to Reconcile Net Income to
Net Cash Provided by (Used in) Operating Activities:
Depreciation, Depletion and Amortization 112,503
Non-Cash Expense 15,163
Deferred Income Taxes 9,789
------------
156,458
Changes in Operating Assets and Liabilities
Restricted Cash Deposits (7,172,149)
Accounts Receivable (1,695,000)
Prepaid Expenses (181,022)
Accounts Payable 10,962,454
------------
NET CASH PROVIDED BY OPERATING ACTIVITIES 2,070,741
------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchases of Fixed Assets (69,645)
Oil and Gas Property Additions (9,545,743)
Noncurrent Restricted Cash Deposits (2,607,648)
------------
NET CASH USED IN INVESTING ACTIVITIES (12,223,036)
------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Sale of Preferred Stock 25,000,000
Offering Costs (896,103)
------------
NET CASH PROVIDED BY FINANCING ACTIVITIES 24,103,897
------------
NET INCREASE IN CASH 13,951,602
CASH - BEGINNING OF PERIOD --
------------
CASH - END OF PERIOD $ 13,951,602
============
The accompanying notes are an integral part of the financial statements.
66
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 2000
NOTE 1-ORGANIZATION AND NATURE OF OPERATIONS
Gryphon Exploration Company, a Delaware corporation, (Gryphon or the Company) is
a non-public, Houston-based company formed for the purpose of oil and gas
exploration, development and exploitation. The Company is currently engaged in
the exploration for oil and natural gas along the Gulf Coast of Louisiana, in
the shallow waters of the Gulf of Mexico. The Company began its oil and gas
activities in October 2000.
On October 11, 2000, Gryphon completed a transaction with Warburg, Pincus Equity
Partners, L.P., (Warburg) a global private equity fund based in New York, and
Cheniere Energy, Inc. (Cheniere) to fund an exploration program on approximately
8,800 square miles of seismic data in the Gulf of Mexico (the Louisiana Data
Set). Cheniere contributed selected net assets and liabilities in exchange for
100% of the common stock of Gryphon and $2,000,000 in cash (36.8% voting
interest after conversion of Gryphon's preferred stock). Such assets include:
the Louisiana Data Set, certain offshore leases, a prospect then being drilled,
an exploration agreement with an industry partner (described in Note 5) and
certain other assets and liabilities. The net assets received from Cheniere were
recorded at their estimated fair value at the date of the transaction. Warburg
contributed $25,000,000 and received Gryphon preferred stock, with an 8%
cumulative dividend, convertible into 63.2% of Gryphon's common stock. Cheniere
and Warburg also agreed, under certain circumstances, to contribute an
additional $75,000,000 to Gryphon, proportionate to their respective ownership
interests.
NOTE 2-SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The financial statements include the accounts of Gryphon Exploration Company.
Oil and Gas Properties
The Company follows the full cost method of accounting for its oil and gas
properties. Under this method, all productive and nonproductive exploration and
development costs incurred for the purpose of finding oil and gas reserves are
capitalized. Such capitalized costs include lease acquisition, geological and
geophysical work, delay rentals, drilling, completing and equipping oil and gas
wells, together with internal costs directly attributable to property
acquisition, exploration and development activities.
The costs of the Company's oil and gas properties, including the estimated
future costs to develop proved reserves, are depreciated (upon commencement of
production) using a composite units-of-production rate based on estimates of
proved reserves. Investments in unproved properties and major development
projects are not amortized until proved reserves associated with the projects
can be determined or until impairment occurs. If the results of an assessment
indicate that the properties are impaired, the amount of the impairment is added
to the capitalized costs to be amortized. Net capitalized costs are limited to a
capitalization ceiling, calculated on a quarterly basis as the aggregate of the
present value, discounted at 10%, of estimated future net revenues from proved
reserves, based on current economic and operating conditions, plus the lower of
cost or fair market value of unproved properties, less related income tax
effects.
The Company's allocation of 3D seismic exploration costs to proved properties
involves an estimate of the total reserves to be discovered in the project. It
is reasonably possible, based on the results obtained from future drilling, that
revisions to this estimate could occur within the next twelve months, which
could affect the Company's capitalization ceiling.
Sales of proved and unproved properties are accounted for as adjustments of
capitalized costs with no gain or loss recognized, unless such adjustments would
significantly alter the relationship between capitalized costs and proved oil
and gas reserves.
Revenue Recognition
Revenues from the sale of oil and gas produced are recognized upon passage of
title, net of royalty interests. When sales volumes differ from the Company's
entitled share, an overproduced or underproduced imbalance occurs. To the extent
the overproduced imbalance exceeds the Company's share of the remaining
estimated proved natural gas reserves for a given property, the Company records
a liability. At December 31, 2000 the Company had no gas imbalances.
67
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS--(Continued)
DECEMBER 31, 2000
Fixed Assets
Fixed assets are recorded at cost. Repairs and maintenance costs are charged to
operations as incurred. Depreciation is computed using the straight- line method
calculated to amortize the cost of assets over their estimated remaining useful
lives, which are estimated as 9-17 months for software and computer equipment,
18 months for office furnishings and 3 years for leasehold improvements. Upon
retirement or other disposition of property and equipment, the cost and related
depreciation is removed from the accounts and the resulting gains or losses are
recorded.
Offering Costs
Offering costs consist primarily of placement fees, professional fees and
printing costs. These costs are charged against the related proceeds from the
sale of equity securities in the periods in which they occur.
Income Taxes
Provisions for income taxes are based on taxes payable or refundable for the
current year and deferred taxes on temporary differences between the amount of
taxable income and pretax financial income and between the tax bases of assets
and liabilities and their reported amounts in the financial statements. Deferred
tax assets and liabilities are included in the financial statements at currently
enacted income tax rates applicable to the period in which the deferred tax
assets and liabilities are expected to be realized or settled as prescribed in
Statement of Financial Accounting Standards (SFAS) No. 109, Accounting for
Income Taxes. As changes in tax laws or rates are enacted, deferred tax assets
and liabilities are adjusted through the current period's provision for income
taxes.
Stock-Based Compensation
SFAS No. 123, Accounting for Stock-Based Compensation, encourages, but does not
require, companies to record compensation cost for stock-based employee
compensation plans at fair value. The Company has chosen to continue to account
for stock-based compensation issued to employees using the intrinsic value
method prescribed in Accounting Principles Board (APB) Opinion No. 25,
Accounting for Stock Issued to Employees, and related interpretations.
Accordingly, compensation cost for stock options is measured as the excess, if
any, of the market price of the Company's stock at the date of the grant over
the amount an employee must pay to acquire the stock. The Company grants options
at or above the market price of its common stock at the date of each grant.
Cash Equivalents
The Company classifies all investments with original maturities of three months
or less as cash equivalents.
Restricted Cash Deposits
Restricted cash deposits represent deposits reserved for the funding of
contractual drilling costs on behalf of the Company and its working interest
partners.
Fair Value of Financial Instruments
The carrying amounts of cash and cash equivalents, accounts receivable and
accounts payable approximate fair value because of the short maturity of those
instruments.
Commodity Price Risk
The Company produces and sells natural gas, crude oil and condensate. As a
result, the Company's financial results can be significantly affected as these
commodity prices fluctuate widely in response to changing market forces. The
Company has not entered into any hedging or derivative transactions.
68
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS--(Continued)
DECEMBER 31, 2000
Use of Estimates
The preparation of financial statements in conformity with generally accepted
accounting principles requires that the Company make estimates and assumptions
that affect the amounts reported in the financial statements and the
accompanying notes. Actual results could differ from those estimates. Management
believes its estimates are reasonable.
New Accounting Pronouncements
In June 1998, the Financial Accounting Standards Board (FASB) issued Statement
of Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities. In June 1999, the FASB extended the adoption
date of SFAS 133 until January 1, 2001, through the issuance of SFAS No. 137,
Deferral of the Effective Date of SFAS 133. In June 2000, the FASB issued SFAS
No. 138, Accounting for Certain Derivative Instruments and Certain Hedging
Activities, which also amended SFAS 133. SFAS 133, as amended requires that
companies recognize all derivative instruments as either assets or liabilities
on the balance sheet and measure those instruments at fair value. Changes in the
fair value of derivatives are recorded each period in current earnings or other
comprehensive income depending on their designation, their intended use, or
their ability to qualify as hedges. The Company adopted SFAS 133 in the first
quarter of 2001; such adoption did not have a material impact on its financial
statements.
In December 1999, the Securities and Exchange Commission issued Staff Accounting
Bulletin (SAB) No. 101, Revenue Recognition in Financial Statements. SAB No. 101
was implemented in 2000 and did not have a material effect on the Company's
financial statements.
NOTE 3-FIXED ASSETS
Fixed assets consist of the following:
December 31,
2000
----------------
Furniture and Fixtures $ 71,024
Computers and Office Equipment 597,217
Other 95,715
---------------
763,956
Less Accumulated Depreciation (112,503)
---------------
Fixed Assets, Net $ 651,453
===============
69
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS--(Continued)
DECEMBER 31, 2000
NOTE 4-OIL AND GAS PROPERTIES
Investments in oil and gas properties were as follows at December 31, 2000:
December 31,
2000
-----------------
Oil and gas properties:
Proved $ 2,727,143
Unproved 15,469,010
-----------------
18,196,153
Less accumulated depreciation,
depletion and amortization -
-----------------
$ 18,196,153
=================
There was no production from the Company's proved reserves as of December 31,
2000. The Company capitalized as oil and gas property costs $98,032 of general
administrative expenses directly related to its exploration and development
activities in 2000. Noncurrent restricted cash deposits represent amounts
advanced by the Company into escrow or deposit accounts related to its portion
of drilling costs under contractual arrangements.
The Company has made a substantial investment in acquiring, processing and
reprocessing its 3D seismic database covering an 8,800-square-mile project area
in the Gulf of Mexico. The costs of this project become subject to amortization
on a ratable basis as the oil and gas reserves expected to be recovered from the
project are discovered. The Company commenced drilling exploratory wells in
December 2000 related to its unproved properties and anticipates completing
drilling activities sufficient to fully evaluate the properties within three to
five years. Interpretation of this data is ongoing.
NOTE 5-EXPLORATION AGREEMENT
The Company is party to an exploration agreement with an industry partner. This
exploration agreement was contributed by Cheniere (Note 1). Under the terms of
the agreement, Gryphon's exploration partner acquired an option to participate
at a 50% working interest level in any drilling prospect generated by Gryphon
through August 2001 within a defined area of mutual interest in the Gulf of
Mexico. Gryphon receives a fixed management fee of $230,000 per month from its
partner, representing partial reimbursement of general and administrative
expenses over the term of the agreement (through August 31, 2001). In addition,
Gryphon's partner pays a disproportionate share of the cost of leasing and of
the initial test well on each prospect. Gryphon is the operator of the drilling
program. The management fee payments were credited as a recovery of general and
administrative expenses. Management fees received by Gryphon in 2000 totaled
$615,807.
NOTE 6-INCOME TAXES
From its inception through December 31, 2000, the Company has recorded a loss
for federal income tax reporting purposes and deferred income taxes of $9,789.
At December 31, 2000, the Company had net operating loss (NOL) carryforwards for
tax reporting purposes of approximately $2,032,000.
Deferred tax assets and liabilities reflect the net tax effect of temporary
differences between the carrying amount of assets and liabilities for financial
reporting purposes and amounts used for income tax purposes. The Company
recorded a deferred tax liability of approximately $1,174,000 to account for the
difference between the tax basis of assets contributed by Cheniere and the
estimated fair value of those assets at the date of inception.
70
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS--(Continued)
DECEMBER 31, 2000
Significant components of the Company's deferred tax assets and liabilities at
December 31, 2000 are as follows:
December 31,
Deferred Tax Asset (Liability) 2000
---------------------------------- ----------------
NOL $ 751,671
Oil and gas properties and fixed assets (1,935,460)
-----------
Net deferred tax liability $(1,183,789)
===========
Net operating loss carryforwards expire in 2020.
NOTE 7-PREFERRED STOCK
At December 31, 2000, the Company had 25,000 shares of its 8% convertible
preferred stock issued and outstanding. The preferred stock is convertible at
the option of the holder at a rate of $100 per share of common stock at any time
after the holders of a majority of the preferred stock execute a written consent
permitting a conversion of the preferred stock or, if earlier, at any time after
August 31, 2010. In the event the holders of a majority of the preferred stock
vote to convert all of their shares of preferred stock into common stock, all
shares of preferred stock shall automatically be converted, without further
action by the Company or its shareholders. In addition, the Company has the
right, at its option, to convert shares of preferred stock into common stock
upon the closing of a firm commitment qualified public offering. Holders of
preferred stock are entitled to vote, on an as converted basis, on all matters
as to which holders of common stock are entitled to vote, in the same manner and
with the same effect as such holders of common stock, voting together with the
holders of common stock as one class. Each share of preferred stock has a
liquidation preference of $1,000. Dividends accrue at a rate of 8% per annum,
become payable quarterly as declared, and are cumulative and payable in the
event of liquidation of the Company. At December 31, 2000, there were $445,652
in undeclared dividends in arrears.
NOTE 8-STOCK-BASED COMPENSATION
In 2000, the Company established the Gryphon Exploration Company 2000 Stock
Option Plan (the Option Plan). The Option Plan allows for the issuance of
options to purchase up to 64,400 shares of Gryphon common stock at an exercise
price of $100.00 per share during 2000 and 2001. The Company has reserved 64,400
shares of common stock for issuance upon the exercise of options which have been
granted or which may be granted. The term of options granted under the Option
Plan is generally ten years. Vesting occurs over a three-year period, one third
on each anniversary of the grant date. Grants made by the Company during 2000
are summarized in the following table:
December 31,
2000
------------
Outstanding at beginning of period -
Options granted at an exercise price of $100.00 per share 39,750
Options canceled (350)
--------
Outstanding at end of period 39,400
========
Exercisable at end of period -
========
Weighted average exercise price of options outstanding $ 100.00
========
Weighted average exercise price of options exercisable N/A
========
Weighted average fair value of options granted during the
period $ 0.24
========
Weighted average remaining contractual life of options
outstanding 9.8 years
71
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS--(Continued)
DECEMBER 31, 2000
The following table summarizes information about fixed options outstanding at
December 31, 2000.
Weighted Average
Exercise Number Remaining
Price Outstanding Contractual Life (Years)
----------------- -------------- -------------------------
$100.00 39,400 9.8
--------------
39,400
==============
The fair value of options is calculated using the Black-Scholes option pricing
model. Assumptions used for the period from inception (October 11, 2000) through
December 31, 2000, were: no dividend yield, no volatility, risk- free interest
rate of 5.6%, and expected life of the options of 5.0 years. The pro forma
effect on the Company's net income had it adopted the optional recognition
provisions of SFAS No. 123 for 2000 would be to decrease the reported net income
by $580.
NOTE 9-RELATED PARTY TRANSACTIONS
Under the terms of the Contribution and Subscription Agreement dated October 11,
2000 by and among the Company, Cheniere and the other investors listed therein,
Gryphon provided office space to Cheniere at no cost from the closing date of
October 11, 2000 until Cheniere relocated in December 2000, and Cheniere is
providing accounting and cash management services to Gryphon without charge for
six months following the closing date. The values of the office space and the
accounting and cash management services offset and were not significant to the
Company.
Cheniere served as contract operator throughout 2000 for the well contributed to
Gryphon on which drilling was underway at the date of Gryphon's inception.
Cheniere received industry standard overhead reimbursements from all working
interest owners, including Gryphon, in accordance with the terms of the joint
interest operating agreement.
NOTE 10-COMMITMENTS AND CONTINGENCIES
The Company has entered into an office lease agreement with a non- cancelable
term which runs through January 2003. Future minimum lease payments are
$236,259, $236,259 and $19,688 for the years ended December 31, 2001, 2002 and
2003, respectively. Total rental expense for office space for the period from
inception (October 11, 2000) through December 31, 2000 was $56,519.
At the time of its inception, Gryphon acquired a master license agreement
covering the license of approximately 8,800 square miles of 3-D seismic data in
the Gulf of Mexico. In connection with the license agreement, the Company has
made a commitment to reprocess certain of the seismic data and to pay a fee for
such reprocessing as the reprocessed data are delivered. At December 31, 2000,
the Company had contingent commitments of approximately $800,000 related to
future deliveries of reprocessed data.
72
GRYPHON EXPLORATION COMPANY
NOTES TO FINANCIAL STATEMENTS--(Continued)
DECEMBER 31, 2000
NOTE 11-SUPPLEMENTAL DISCLOSURES OF NON-CASH TRANSACTIONS
At the time of its inception, the Company received a contribution of net assets
which were recorded at their estimated fair value and which are summarized as
follows:
Inception
(October 11, 2000)
---------------------
Prepaid expenses $ 1,042,119
Unproved oil and properties 9,379,534
Fixed assets 694,310
Accounts payable (2,050,044)
-----------
Net assets contributed at inception $ 9,065,919
===========
Additionally, the Company recorded a deferred tax liability of approximately
$1,174,000 to account for the difference between the tax basis of assets
contributed by Cheniere and the estimated fair value of those assets at the date
of inception.
73
GRYPHON EXPLORATION COMPANY SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS OIL
AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
COSTS INCURRED IN OIL AND GAS PRODUCING ACTIVITIES
Presented below are costs incurred in oil and gas property acquisition,
exploration and development activities:
December 31,
2000
-----------------
Acquisition of properties:
Proved properties $ -
Unproved properties 7,875,590
Exploration costs 2,018,442
Development costs 728,866
-----------
10,622,898
Assets contributed at inception 7,573,255
-----------
Total $18,196,153
===========
The above amounts include $98,032 of capitalized general and administrative
expenses directly related to property acquisition, exploration and development.
CAPITALIZED COSTS RELATED TO OIL AND GAS PRODUCING ACTIVITIES
The following table presents total capitalized costs of proved and unproved
properties and accumulated depreciation, depletion and amortization related to
oil and gas producing operations:
December 31,
2000
-----------------
Proved properties $ 2,727,143
Unproved properties 15,469,010
-----------
18,196,153
Accumulated depreciation, depletion and amortization -
-----------
$18,196,153
===========
The Company commenced drilling exploratory wells in December 2000 related to its
unproved properties and anticipates completing drilling activities sufficient to
fully evaluate the properties within three to five years. Interpretation of this
data is ongoing.
RESULTS OF OPERATIONS FROM OIL AND GAS PRODUCING ACTIVITIES
Oil and gas producing activities had not yet commenced as of December 31, 2000.
74
GRYPHON EXPLORATION COMPANY SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS OIL
AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
RESERVE QUANTITIES
Estimates of proved reserves of the Company and the related standardized measure
of discounted future net cash flow information are based on the reports
generated by independent petroleum engineers in accordance with the rules and
regulations of the SEC. The independent engineers' estimates were based upon a
review of production histories and other geologic, economic, ownership and
engineering data provided by the Company. These estimates represent the
Company's interest in the reserves associated with its properties. All of the
Company's oil and gas reserves are located within the United States and its
territorial waters.
The Company's estimates of its proved reserves and proved developed reserves of
oil and gas as of December 31, 2000 and the changes in its proved reserves are
as follows:
2000
----------------------------
Oil Gas
(Bbls) (Mcf)
----------- --------------
Proved reserves:
Beginning of year - -
Extensions, discoveries and other additions 2,640 1,674,000
----- ---------
End of year 2,640 1,674,000
===== =========
Proved developed reserves:
Beginning of year - -
End of year 2,640 1,674,000
===== =========
There are numerous uncertainties inherent in estimating quantities of proved
reserves and in projecting future rates of production and future amounts and
timing of development expenditures, including many factors beyond the control of
the Company. Reserve engineering is a subjective process of estimating
underground accumulations of crude oil and natural gas that cannot be measured
in an exact manner, and the accuracy of any reserve estimate is a function of
the quality of available data and of engineering and geological interpretation
and judgment. Estimates of proved undeveloped reserves are inherently less
certain than estimates of proved developed reserves. The quantities of oil and
gas that are ultimately recovered, production and operating costs, the amount
and timing of future development expenditures, geologic success and future oil
and gas sales prices may all differ from those assumed in these estimates. In
addition, the Company's reserves may be subject to downward or upward revision
based upon production history, purchases or sales of properties, results of
future development, prevailing oil and gas prices and other factors.
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
The standardized measure of discounted future net cash flows was calculated by
applying year-end prices to estimated future production, less future
expenditures (based on year-end costs) to be incurred in developing and
producing such proved reserves and the estimated effect of future income taxes
based on the current tax law. The resulting future net cash flows were
discounted using a rate of 10% per annum.
The standardized measure of discounted future net cash flow amounts contained in
the following tabulation does not purport to represent the fair market value of
oil and gas properties. No value has been given to unproved properties. There
are significant uncertainties inherent in estimating quantities of proved
reserves and in projecting rates of production and the timing and amount of
future costs. Future realization of oil and gas prices over the remaining
reserve lives may vary significantly from current prices. In addition, the
method of valuation utilized, based on year-end prices and costs and the use of
a 10% discount rate, is not necessarily appropriate for determining fair value.
The standardized measure of discounted future net cash flows relating to proved
oil and gas reserves is as follows:
75
GRYPHON EXPLORATION COMPANY SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS OIL
AND GAS RESERVES AND RELATED FINANCIAL DATA
(unaudited)
December 31,
2000
----------------
Future gross revenues $ 17,645,344
============
Less - future costs:
Production (900,581)
Development and dismantlement (1,205,810)
------------
Future net cash flows before income taxes 15,538,953
Less - 10% annual discount for estimated timing of cash flows (2,471,729)
------------
Present value of future net cash flows before income taxes 13,067,224
Less - present value of future income taxes (3,928,304)
------------
Standardized measure of discounted future net cash flows $ 9,138,920
============
The following table summarizes the principal sources of change in the
standardized measure of discounted future net cash flows:
December 31,
2000
---------------
Standardized measure - beginning of period $ -
Extensions, discoveries and other additions 9,138,920
----------
Standardized measure - end of period $9,138,920
==========
The standardized measure amounts are based on year-end prices of $29.72 per
barrel of oil and $10.60 per mcf of gas. The Company had not commenced
production of oil and gas as of December 31, 2000. The Company may receive
amounts different than those incorporated into the standardized measure of
discounted cash flow for a number of reasons, including changes in prices.
Therefore, the present value shown above should not be construed as the current
market value of the estimated oil and gas reserves attributable to the Company's
properties.
76