SECURITIES AND EXCHANGE COMMISSION
                             Washington, D.C. 20549


                                   FORM 10-KSB/A

 [X] Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange
     Act of 1934

                   For the fiscal year ended December 31, 2003

 [ ] Transition Report Pursuant to Section 13 or 15(d) of the Securities
     Exchange Act of 1934

                        Commission file number No 0-26509

                 ----------------------------------------------
                            NATIONAL COAL CORPORATION
                 ----------------------------------------------
        (Exact name of small business issuer as specified in its charter)

                       SOUTHERN GROUP INTERNATIONAL, INC.
           ----------------------------------------------------------
                                  (Former name)

                               Florida 65-06001212
                         -------------- ----------------
            (State or other jurisdiction of (IRS Employer ID Number)
                         incorporation or organization)

                     319 Ebenezer Road, Knoxville, TN 37923
                     --------------------------------------
                    (Address of principal executive offices)

                                 (865) 769-3749
                            Issuer's Telephone Number

                         69 Mall Drive, Comack, NY 11725
               ---------------------------------------------------
              (Former name, former address and former fiscal year,
                          if changed since last report)

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:

As of March 23, 2004, the issuer had 42,552,162 shares of common stock, par
value $.0001 per share issued and outstanding.


<PAGE>
 2003 FORM 10-K ANNUAL REPORT

                                TABLE OF CONTENTS

PART I                                                                     PAGE

     Item 1.   Description of Business                                         1
     Item 2.   Description of Property                                        23
     Item 3.   Legal Proceedings                                              24
     Item 4.   Submission of Matters to a Vote of Security Holders            24


PART II

     Item 5.   Market for Common Equity and Related Stockholder Matters       25
     Item 6.   Management's Discussion and Analysis or Plan of Operation      26
     Item 7.   Financial Statements                                           44
     Item 8.   Changes in and Disagreements With Accountants on Accounting    45
               and Financial Disclosure
     Item 8a.  Controls and Procedures                                        45


PART III

     Item 9.   Directors, Executive Officers, Promoters and Control Persons;
               Compliance with Section 16(a) of the Exchange Act              46
     Item 10.  Executive Compensation                                         48
     Item 11.  Security Ownership of Certain Beneficial Owners and Management 49
     Item 12.  Certain Relationships and Related Transactions                 50
     Item 13.  Exhibits and Reports on Form 8-K                               52
     Item 14.  Principal Accountant Fees and Services                         52

SIGNATURES                                                                    54


<PAGE>



                                     PART I

Item 1.       Description of Business

                               CORPORATE OVERVIEW

     Southern Group International, Inc. was incorporated in the State of Florida
on August 10, 1995, and was inactive until 2003.

         On March 28, 2003, National Coal Corporation, a Tennessee corporation,
entered into a Share Purchase Agreement whereby it purchased 500,000 shares of
Southern Group International, Inc., a Florida corporation, from Surinder
Rametra. Such shares were cancelled and returned to the treasury of Southern
Group International, Inc. as of April 11, 2003. On April 11, 2003, the Board of
Southern Group International, Inc. approved a Plan and Agreement of
Reorganization whereby all the outstanding shares of National Coal Corporation
(Tennessee) were exchanged on April 30, 2003 for 34,200,000 shares of Southern
Group International, Inc. After the transaction, Jon Nix, Farrald Belote, Jr.,
Charles Kite, and Jeanne Bowen, or their designees, the principal owners of
National Coal Corporation (Tennessee) prior to the reorganization, owned a total
of 30,700,000 shares of Southern Group International, Inc.

         Articles of Amendment to the Articles of Incorporation were filed with
the Florida Secretary of State's Office on August 4, 2003 changing the name of
Southern Group International, Inc. to National Coal Corporation ("National Coal"
or the "Company" hereafter). National Coal Corporation (Tennessee) operates as a
wholly owned subsidiary of National Coal Corporation, a Florida corporation. The
Company trades on the "Pink Sheets" under the symbol "NLCP.PK."

         The Company engages in coal production by locating, assembling,
acquiring or leasing, assessing, permitting and developing coal properties in
Eastern Tennessee in the Central Appalachian coal region. The Company, after
obtaining permits from the Department of the Interior, mines said properties, or
contracts with independent mine operators, for extraction of the coal minerals
on a negotiated fee basis. Some contracts may be on a per ton basis, and some
may be on a cost plus basis. The variance is usually due to varying extraction
conditions and circumstances.

         The principal activity of the Company is coal mining. The Company
currently owns, in fee simple, the coal mineral rights to the New River Tract
assemblage, which consists of approximately sixty-five thousand (65,000) acres
that lie in Anderson, Campbell and Scott Counties, approximately twenty-five
miles northwest of Knoxville, Tennessee. These mineral rights revert back to the
surface owner on June 5, 2093. At the present time there are two separate areas
located on the New River Tract assemblage that are producing coal which include
(1) a surface mine situated in Devonia, Tennessee (Patterson Mountain), and (2)
a portion of the New River Tract mined by U.S. Coal, Inc., an independent mine
operator that pays royalties to the Company on coal production.

         The Company currently sells its production into the spot market or
sells coal based on short-term contracts, but in the future intends to seek
long-term supply contracts. No such long-term contracts have been negotiated to
date.

         Many of the Company's properties have been subject to limited
production in the past. Some of the properties were abandoned by previous
producers due to poor market conditions, uneconomical production, high labor
costs and/or reclamation bond difficulties.

         Reclamation bonds are obtained and maintained by the Company for each
producing property. Bonds typically take the form of cash deposits with the U.S.
Department of the Interior, Office of Surface Mining. In theory, insurance bonds
could be used, but such are extremely difficult and time consuming for small
companies to obtain in the market.

                                      -1-

<PAGE>




         The Company maintains an umbrella liability insurance policy for all of
its operations, and requires liability policies to be furnished by contract
operators, naming the Company as a co-insured.

         The coal industry has been highly competitive with very thin margins in
recent years. Only in the past two years, in the opinion of management, have the
economics begun to look favorable to coal again. This situation is due to, among
other things, the surge in prices of natural gas. The price increases of natural
gas, on a Btu basis, have reached the point that coal fired power plants, using
the latest clean air compliant scrubber technology, can be price competitive
with natural gas fired plants.

         The Company intends to exploit its mineral rights by opening mines, as
its capital will allow, but it can only open a mine with an estimated $500,000
to $750,000 per mine, including bonds or cash deposited. Due to the operating
capital constraints, if the Company cannot raise such needed additional amounts
by loans or private placements, it will prevent the Company from expanding its
mining operations beyond the current operations.

                           GLOSSARY OF SELECTED TERMS

Anthracite.  The highest rank of economically  usable coal with moisture content
less than 15% by weight and heating value as high as 15,000 Btu per pound. It is
jet black with a high luster. It is mined primarily in Pennsylvania.

Appalachia.  The coal producing states of Alabama,  Georgia,  eastern  Kentucky,
Maryland,  North  Carolina,  Ohio,  Pennsylvania,  Tennessee,  Virginia and West
Virginia.   Ash.  The   impurities   consisting  of  iron,   alumina  and  other
incombustible  matter contained in coal. Since ash increases the weight of coal,
it adds to the cost of handling  and can affect the burning  characteristics  of
coal.

Assigned  Reserves.  The  coal  that  is  committed  to be  mined  at  operating
facilities.

Bituminous Coal. The most common type of coal with moisture content less than
20% by weight and heating value of 10,500 to 14,000 Btu per pound. It is dense
and black and often has well-defined bands of bright and dull material.

British Thermal Unit or "Btu." A measure of the thermal energy required to raise
the  temperature of one pound of pure liquid water one degree  Fahrenheit at the
temperature at which water has its greatest density (39 degrees Fahrenheit).

Clean Air Act Amendments of 1990. A comprehensive set of amendments to the
federal law governing the nation's air quality. The Clean Air Act was originally
passed in 1970 to address significant air pollution problems in our cities. The
1990 amendments broadened and strengthened the original law to address specific
problems such as acid deposition, urban smog, hazardous air pollutants and
stratospheric ozone depletion.

Coal Seam. Coal deposits occur in layers. Each layer is called a "seam."

Coke.  A hard,  dry carbon  substance  produced  by heating  coal to a very high
temperature  in the absence of air. Coke is used in the  manufacture of iron and
steel.  Its production  results in a number of useful  byproducts.  Coking Coal.
Coal used to make coke and interchangeably referred to as metallurgical coal.

Compliance  Coal. The coal having a sulfur dioxide content of 1.2 pounds or less
per million Btu, as required by Phase II of the Clean Air Act.

                                      -2-
<PAGE>




Continuous  Mining.  A form of underground,  room-and-pillar  mining that uses a
continuous  mining  machine to cut coal from the seam and load it onto conveyors
or into shuttle cars in a continuous operation.

Deep Mine.  An underground coal mine.

Dragline.  A large  excavating  machine  used in the surface  mining  process to
remove overburden.

Dragline  Mining.  A form  of  mining  where  large  capacity,  electric-powered
draglines remove  overburden to expose the coal seam.  Smaller shovels load coal
in haul trucks for  transportation to the preparation plant and then to the rail
loadout.

Fossil Fuel. Fuel such as coal,  petroleum or natural gas formed from the fossil
remains of organic material.

Highwall Mining. A technique of using a continuous  mining machine under robotic
remote control to mine coal from underground.

Illinois  Basin.  The coal  producing  area in  Illinois,  southern  Indiana and
western Kentucky.

Lignite. The lowest rank of coal, which contains a high moisture content of up
to 45% by weight and heating value of 6,500 to 8,300 Btu per pound. It is
brownish black and tends to oxidize and disintegrate when exposed to air.

Longwall Mining. A form of underground mining in which a panel or block of coal,
generally at least 700 feet wide and often over one mile long, is completely
extracted. The working area is protected by a moveable, powered roof support
system.

Metallurgical Coal. Various grades of coal suitable for carbonization to
make coke for steel manufacture. Also known as "met" coal, it possesses four
important qualities: volatility, which affects coke yield; the level of
impurities, which affects coke quality; composition, which affects coke
strength; and basic characteristics, which affect coke oven safety. Met coal has
a particularly high Btu, but low ash content.

Nitrogen Oxide (NOx). A gas formed in high temperature environments such as coal
combustion. It is a harmful pollutant that
contributes to acid rain.

Non-Compliance  Coal. The coal having a sulfur dioxide  content of more than 1.2
pounds per million Btu.

Overburden. The Layers of earth and rock covering a coal seam. In surface mining
operations, overburden is removed prior to coal
extraction.

Overburden Ratio/Stripping Ratio. The amount of overburden that must be removed
compared to a given quantity of coal. It is commonly expressed in cubic yards
per ton of coal or as a ratio comparing the thickness of the overburden with the
thickness of the coal bed.

Pillar. An area of coal left to support the overlying strata in a mine.  Pillars
are sometimes left permanently to support surface structures.

Powder River Basin. The coal producing area in northeastern Wyoming and
southeastern Montana. This is the largest known source of coal reserves and the
largest producing region in the United States.

Preparation Plant. A coal
processing facility, usually located on a mine site, although one plant may
serve several mines. A preparation plant is a facility for crushing, sizing and
washing coal to prepare it for use by a particular customer. The washing process
has the added benefit of removing some of the coal's sulfur content.

                                      -3-
<PAGE>




Probable Reserves. Reserves for which quantity and grade and/or quality are
computed from information similar to that used for proven reserves, but the
sites for inspection, sampling and measurement are farther apart or are
otherwise less appropriately spaced. The degree of assurance, although lower
than that for proven reserves, is high enough to assume continuity between
points of observation.

Proven Reserves. Reserves for which: (a) quantity is computed from dimensions
revealed in outcrops, trenches, workings or drill holes with grade and/or
quality computed from the results of detailed sampling, and (b) the sites for
inspection, sampling and measurement are spaced so closely and the geologic
character is so well defined that size, shape, depth and mineral content of
reserves are well-established.

Reclamation. A process of restoring land and the environment to an approved
state following mining activities. The process commonly includes "recontouring"
or reshaping the land to its approximate original appearance, restoring topsoil
and planting native grass and ground covers. Reclamation operations are usually
underway before the mining of a particular site is completed. Reclamation is
closely regulated by both state and federal law.

Reserve. That part of a mineral deposit that could be economically and legally
extracted or produced at the time of the reserve determination.

Roof.  A stratum  of rock or other  mineral  above a coal  seam or the  overhead
surface of an underground coal working place. Same as "back" or "top."

Room-and-Pillar  Mining.  The most common method of underground  mining in which
the mine roof is supported  mainly by coal  pillars  left at regular  intervals.
Rooms are placed where the coal is mined; pillars are areas of coal left between
the rooms.  Room-and-pillar  mining is done either by conventional or continuous
mining.

Scrubber   (flue  gas   desulfurization   unit).   Any  of   several   forms  of
chemical/physical  devices which operate to neutralize  sulfur  compounds formed
during coal  combustion.  These devices combine the sulfur in gaseous  emissions
with other chemicals to form inert compounds,  such as gypsum, that must then be
removed for disposal.  Although effective in substantially  reducing sulfur from
combustion gases, scrubbers require about 6% to 7% of a power plant's electrical
output and thousands of gallons of water to operate.

Steam Coal.  Coal used by power plants and  industrial  steam boilers to produce
electricity  or process  steam.  It  generally  is lower in Btu heat content and
higher in volatile matter than metallurgical coal.

Sub-Bituminous  Coal.  A  dull,  black  coal  that  ranks  between  lignite  and
bituminous coal. Its moisture content is between 20% and 30% by weight,  and its
heat content ranges from 7,800 to 9,500 Btu per pound of coal.

Sulfur.  One  of the  elements  present  in  varying  quantities  in  coal  that
contributes to environmental  degradation when coal is burned. Sulfur dioxide is
produced as a gaseous by-product of coal combustion.

Sulfur  Content.  Coal is commonly  classified by its sulfur  content due to the
importance  of sulfur in  environmental  regulations.  "Low  sulfur"  coal has a
variety  of  definitions  but  typically  is used as a  classification  for coal
containing 1.0% or less sulfur.

Surface Mine. A coal mine in which the coal lies near the surface and can be
extracted by removing the covering layer of soil (see "Overburden"). About 60%
of total U.S. coal production comes from surface mines.

Ton. A "short" or net ton is equal to 2,000  pounds.  A "long" or British ton is
2,240 pounds; a "metric" ton is approximately 2,205 pounds. The short ton is the
unit of measure referred to in this document.

                                      -4-
<PAGE>




Truck-and-Shovel Mining. A form of mining where large shovels are used to remove
overburden, which is used to backfill pits after the coal is removed. Smaller
shovels load coal in haul trucks for transportation to the preparation plant or
rail loading facility.

Unassigned  Reserves.  Coal at  inactive  locations  and coal  that has not been
committed,  and that would  require new mine  development,  mining  equipment or
plant facilities before operations could begin on the property.

Underground Mine. Also known as a "deep" mine. Usually located several hundred
feet below the earth's surface, an underground mine's coal is removed
mechanically and transferred by shuttle car or conveyor to the surface. Most
underground mines are located east of the Mississippi River and account for
about 40% of annual U.S. coal production.

Unit Train. A train of 100 or more cars carrying only coal. A typical unit train
can carry at least 10,000 tons of coal in a single shipment.

Western  Bituminous Coal Regions.  The coal producing area including,  the Hanna
Basin in Wyoming,  the Uinta Basin of  northwestern  Colorado and Utah, the Four
Corners  Region  in New  Mexico  and  Arizona  and the Raton  Basin in  southern
Colorado.


                             COAL INDUSTRY OVERVIEW

         The Company obtained the information provided in this "Coal Industry
Overview" regarding future coal production and consumption and future
electricity generation from the Energy Information Administration, the
International Energy Agency, the National Mining Association, Energy Ventures
Analysis, Inc., Resource Data International, Inc. and the National Energy
Technology Laboratory. The Energy Information Administration is the independent
statistical and analytical agency within the U.S. Department of Energy. The
International Energy Agency is an autonomous agency linked with the Organization
for Economic Cooperation and Development whose member countries cooperate in the
development of rational energy programs. The National Mining Association is a
national trade organization that represents the interests of mining before
Congress, the Administration, federal agencies, the judiciary and the media.
Energy Ventures Analysis, Inc. and Resource Data International, Inc. are private
market research firms. The National Energy Technology Laboratory is an agency of
the U.S. Department of Energy. For the definitions of certain technical terms
used in this document, please refer to "Glossary of Terms."
         The Energy Information Administration, the primary source of the data,
bases its forecasts on assumptions about, among other things, trends in various
economic sectors (residential, transportation, industrial, etc.), economic
growth rates, technological improvements and demand for other energy sources.
The Energy Information Administration's Annual Energy Outlook 2003 and
International Energy Outlook 2002 more fully describe these assumptions. The
other sources noted herein do not describe the assumptions upon which they base
their projections.

Introduction

         Coal is one of the world's most abundant, efficient and affordable
natural resources, and is used primarily as fuel for the generation of
electricity. According to the International Energy Agency, in 2000, coal
provided 26% of the world's primary energy supply and was responsible for
approximately 39% of the world's power generation. Coal's share of electricity
generation in the United States was estimated at 50% in 2002.
         As the table below indicates, coal fueled more electricity in the
United States in 2001 than all other fuels combined.

                                      -5-
<PAGE>




Electricity Fuel Sources (based on net generation)

                           1990             1995              2001          2002
                           ----             ----              ----          ----

Coal                       52.5%            51.0%             50.9%        50.2%
Nuclear                    19.0             20.1              20.6         20.3
Hydro                       9.6              9.3               5.8          6.9
Natural Gas                12.3             14.8              17.1         17.9
Other                       6.6              4.8               5.6          4.7
                           -----            -----             -----        -----
Total                      100%             100%              100%          100%

Source: Energy Information Administration Monthly Energy Review, April 2003.

         The United States is the second largest coal producer in the world,
exceeded only by China. Other leading coal producers include Australia, India
and South Africa. The United States has the largest coal reserves in the world,
with an estimated 250 years of supply based on current usage rates. U.S. coal
reserves are more plentiful than U.S. oil or natural gas reserves, with coal
representing more than 85% of the nation's fossil fuel reserves.

     U.S. coal  production has nearly doubled during the past 30 years. In 2002,
total U.S. coal  production was estimated to be 1.1 billion tons.  Approximately
66% of U.S. coal is produced by surface mining methods,  while the remaining 34%
is produced by underground mining methods.

         The U.S. coal industry operates under a highly developed regulatory
regime that governs all mining and mine safety activities, including land
reclamation, which requires mined lands to be restored to a condition equal to
or better than that existing before mining. Coal mining in the United States has
become a relatively safe occupation, relying on sophisticated technology and a
skilled work force to become one of the safest, most productive industries in
the world.

         In recent years, the coal industry has experienced significant gains in
mining productivity, changes in air quality laws, growth in coal consumption and
industry consolidation. According to the Energy Information Administration, the
number of operating mines declined 52% over the past 10 years, while overall
coal production increased approximately 8% over that period. During the same
period, average coal mine productivity nearly doubled due to changes in work
practices, new technologies and an increase in production in the Powder River
Basin coal region, where thick, easily accessible coal seams result in high
productivity. The overall productivity gains contributed to stability in coal
prices during the 1990s. Recent increases in the price of natural gas and other
energy commodities, however, have resulted in the price of coal increasing in
most regions where the Company operates. A notable industry trend has been the
shift to low sulfur coal production, particularly in the Powder River Basin,
driven by the significant regulatory restrictions on sulfur dioxide emissions
from coal-fueled electric generating plants.

Coal Markets

         The Energy Information Administration estimates that approximately 1.1
billion tons of coal were consumed in the United States in 2002 and expects
domestic consumption of coal by electric generators to grow at an annual rate of
1.4% per year from 2001 through 2025, predicated on natural gas price
assumptions of $2.88 per million Btu in 2005 and $3.30 in 2010. Demand from
domestic electric generators accounts for more than 90% of domestic coal
consumption. The Energy Information Administration projects annual coal use
growth by electric generators of nearly 400 million tons by 2025.

                                      -6-
<PAGE>




U.S. Coal Consumption by Sector

         Coal-fueled generation is used in most cases to meet baseload
requirements, so coal use generally grows at the pace of electricity growth.
Gas-fired electric generation, which is used primarily for intermediate and
peak-load demand, is anticipated to gain market share at the expense of nuclear
generation or where peak-load capacity is needed.

Sources of Coal Demand Growth

         In the aggregate, coal-fueled plants currently utilize approximately
70% of their capacity, although the optimal sustainable capacity utilization is
estimated at 85% for a typical plant, and most plants can run at higher rates
for short periods. An increase from 70% capacity utilization to 85% capacity
utilization would translate into approximately 200 million tons of additional
annual coal consumption.
         In addition to expected greater utilization of existing plants, a
number of new coal-fueled generating plants have been announced in recent years
to meet America's needs for inexpensive baseload generating capacity.

Regional Coal Markets

         Over the past several years, largely as a result of sulfur dioxide
emissions limitations mandated by the Clean Air Act, demand has shifted toward
lower sulfur coal. In 1995, Phase I of the Clean Air Act required high sulfur
coal plants to reduce their emissions of sulfur dioxide to 2.5 pounds or less of
sulfur dioxide per million Btu. As a result of a significant switch to very low
sulfur Powder River Basin coal, many Phase I-affected plants over complied with
the sulfur dioxide requirements, creating a surplus of emission allowances that
could be traded within a market for sulfur dioxide emissions credits. In 2000,
Phase II of the Clean Air Act tightened restrictions on sulfur dioxide emissions
from 2.5 pounds or less to 1.2 pounds or less of sulfur dioxide per million Btu.
Surplus emission credits from Phase I allowed some generators to delay
retrofitting old plants with scrubbers. Eventually, owners of these plants will
have to retrofit or switch to Phase II compliance coal, including Powder River
Basin or other low sulfur coal. The following table indicates that the ongoing
shift to Powder River Basin coal is expected to continue.

U.S. Coal Production by Supply Region (in million tons)

                                    Historical       Projected
<TABLE>
<CAPTION>
<S>                                <C>              <C>               <C>              <C>               <C>

                                    2001             2005              2010             2015              2020
                                    ----             ----              ----             ----              ----
Powder River Basin                   408              410               509              563               632
Central/Southern Appalachia          290              272               286              286               280
Northern Appalachia                  143              131               124              120               128
Illinois Basin                        95              103               102              104               107
Other Western US                     103               99               104              117               118
Lignite                               91              101                96               88                86
Other                                  9                9                 9                8                 8
                                    -----            -----             ------           -----             ------
Total                              1,139            1,125             1,230            1,286             1,359
</TABLE>

Source: Energy Information Administration, Annual Energy Outlook 2003.

                                      -7-
<PAGE>




Coal Characteristics

         There are four types of coal: lignite, subbituminous, bituminous and
anthracite. Each has characteristics that make it more or less suitable for
different end uses. In general, coal of all geological composition is
characterized by end use as either "steam coal" or "metallurgical coal,"
sometimes known as "met coal." Steam coal is used by electricity generators and
by industrial facilities to produce steam, electricity or both. Metallurgical
coal is refined into coking coal, which is used in the production of steel. Heat
value and sulfur content, the most important coal characteristics, determine the
best end use of particular types of coal.

Heat Value

         The heat value of coal is commonly measured in Btu per pound of coal.
Coal found in the eastern and midwestern regions of the United States tends to
have a heat content ranging from 10,000 to 15,000 Btu per pound. Most coal found
in the western United States ranges from 8,000 to 10,000 Btu per pound. The
weight of moisture in coal, as sold, is included in references to Btu per pound
of coal in this document, unless otherwise indicated.

         Lignite is a brownish-black coal with a heat content that generally
ranges from 4,500 to 8,500 Btu per pound. Major lignite operations are located
in Louisiana, Montana, North Dakota and Texas. Lignite is used almost
exclusively in power plants located adjacent to or near these mines because any
transportation costs, coupled with mining costs, would render its use
uneconomical. The Company does not have any lignite reserves.

         Subbituminous coal is a black coal with a heat content that ranges from
8,000 to 12,000 Btu per pound. Most subbituminous reserves are located in
Alaska, Colorado, Montana, New Mexico, Washington and Wyoming. Subbituminous
coal is used almost exclusively by electric generators and some industrial
consumers. Bituminous coal is a "soft" black coal with a heat content that
ranges from 9,500 to 15,000 Btu per pound. This coal is located primarily in
Appalachia, Arizona, the Midwest, Colorado and Utah, and is the type most
commonly used for electric generation in the United States. Bituminous coal is
also used for industrial steam purposes and is used in steel production.

     Anthracite  is a "hard"  coal  with a heat  content  that can be as high as
15,000  Btu per  pound.  A limited  amount of  anthracite  deposits  is  located
primarily  in  the  Appalachian  region  of  Pennsylvania.  Anthracite  is  used
primarily for  industrial and home heating  purposes.  The Company does not have
any anthracite reserves.

Sulfur Content

         Sulfur content can vary from seam to seam and sometimes within each
seam. Coal combustion produces sulfur dioxide, the amount of which varies
depending on the chemical composition and the concentration of sulfur in the
coal. Low sulfur coal has a variety of definitions, and in this document "low
sulfur" is referred to coal with sulfur content of 1.0% or less by weight.
Compliance coal refers to coal with a sulfur content of less than 1.2 pounds per
million Btu. The strict emissions standards of the Clean Air Act have increased
demand for low sulfur coal. The Company expects continued high demand for low
sulfur coal as electric generators meet the current Phase II requirements of the
Clean Air Act (1.2 pounds or less of sulfur dioxide per million Btu). U.S.
sulfur dioxide emissions from electricity generation have decreased 30% from
1990 to 2000 levels, while coal consumed by U.S. electric generators has
increased 26% during the same period.

         Subbituminous coal typically has a lower sulfur content than bituminous
coal, but some bituminous coal in Colorado, eastern Kentucky, Tennessee,
southern West Virginia and Utah also has a low sulfur content.

                                      -8-
<PAGE>




         Plants equipped with sulfur-reduction technology, known as "scrubbers,"
which reduce sulfur dioxide emissions by 50% to 95%, can use higher sulfur coal.
Plants without scrubbers can use medium and high sulfur coal by purchasing
emission allowances on the open market or blending that coal with low sulfur
coal. Each allowance permits the user to emit a ton of sulfur dioxide. Some
older coal-fueled plants have been retrofitted with scrubbers. Any new
coal-fueled generation built in the United States will likely use clean coal
technologies to remove the majority of sulfur dioxide, nitrogen oxide and
particulate matter emissions.

Other

         Ash is the inorganic residue remaining after the combustion of coal. As
with sulfur content, ash content varies from seam to seam. Ash content is an
important characteristic of coal because electric generating plants must handle
and dispose of ash following combustion.

         Moisture content of coal varies by the type of coal, the region where
it is mined and the location of coal within a seam. In general, high moisture
content decreases the heat value and increases the weight of the coal, thereby
making it more expensive to transport. Moisture content in coal, as sold, can
range from approximately 5% to 30% of the coal's weight.

     When some types of coal are  super-heated  in the  absence of oxygen,  they
form a hard, dry, caking form of coal called coke. Steel production uses coke as
a fuel and reducing agent to smelt iron ore in a blast furnace.

Coal Mining Techniques

         Coal mining operations commonly use four distinct techniques to extract
coal from the ground. The most appropriate technique is determined by coal seam
characteristics such as location and recoverable reserve base. Drill hole data
are used initially to define the size, depth and quality of the coal reserve
area before committing to a specific extraction technique. All coal-mining
techniques rely heavily on technology; consequently, technological improvements
have resulted in increased productivity. The four most common mining techniques
are (1) continuous mining, (2) longwall mining, (3) truck-and-shovel mining and
(4) dragline mining.

         It is generally easier to mine coal seams that are thick and located
close to the surface than thin underground seams. Typically, coal-mining
operations will begin at the part of the coal seam that is easiest and most
economical to mine. In the coal industry, this characteristic is referred to as
"low ratio." As the seam is mined, it becomes more difficult and expensive to
mine because the seam either becomes thinner or protrudes more deeply into the
earth, requiring removal of more material over the seam, known as the
"overburden." For example, many seams of coal in the Midwest are five to 10 feet
thick and located hundreds of feet below the surface. In contrast, seams in the
Powder River Basin of Wyoming may be 80 feet thick and located only 50 feet
below the surface.

         Once the raw coal is mined, it is often crushed, sized and washed in
preparation plants where the product consistency and heat content are improved.
This process involves crushing the coal to the required size, removing
impurities and, where necessary, blending it with other coal to match customer
specifications.

Continuous Mining

         Continuous mining is an underground mining method in which main airways
and transportation entries are developed and remote-controlled continuous miners
extract coal from "rooms," leaving "pillars" to support the roof. Shuttle cars
transport coal from the face to a conveyor belt for transport to the surface.
This method is often used to mine smaller coal blocks or thin seams, and seam
recovery is typically approximately 50%. Productivity for continuous mining
averages 25 to 50 tons per miner shift.

                                      -9-
<PAGE>





Longwall Mining

         Longwall mining is an underground mining method that uses hydraulic
jacks or shields, varying from five feet to 12 feet in height, to support the
roof of the mine while a mobile-cutting sheerer advances through the coal. Chain
belts then move the coal to a standard deep mine conveyer system for delivery to
the surface. Continuous mining is used to develop access to long rectangular
panels of coal, which are then mined with longwall equipment, allowing
controlled subsidence behind the advancing machinery. Longwall mining is highly
productive, but it is effective only for large blocks of medium to thick coal
seams. High capital costs associated with longwall mining demand a large,
contiguous reserve base. Seam recovery using longwall mining is typically 70%,
and productivity averages 40 to 80 tons per miner shift.

Truck-and-Shovel Mining

         Truck-and-shovel mining is an open-cast method that uses large
electric-powered shovels to remove overburden, which is used to backfill pits
after coal removal. Shovels load coal in haul trucks for transportation to the
preparation plant or rail loadout. Seam recovery using the truck-and-shovel
method is typically 90%. Productivity depends on equipment, geological
composition and the ratio of overburden to coal. Productivity varies between 250
to 400 tons per miner shift in the Powder River Basin to 30 to 80 tons per miner
shift in eastern U.S. regions.

Dragline Mining

         Dragline mining is an open-cast method that uses large capacity
electric-powered draglines to remove overburden to expose the coal seams.
Shovels load coal in haul trucks for transportation to the preparation plant and
then to the rail loadout. Truck capacity can range from 80 to 400 tons per load.
Seam recovery using the dragline method is typically 90% or more, and
productivity levels are similar to those for truck-and-shovel mining.

Technology

         Coal mining technology is continually evolving and improving, among
other things, underground mining systems and larger earth-moving equipment for
surface mines. For example, longwall mining technology has increased the average
recovery of coal from large blocks of underground coal from 50% to 70%. At
larger surface mines, haul trucks have capacities of 240 to 400 tons, which is
nearly double the maximum capacity of the largest haul trucks used a decade ago.
This increase in capacity, along with larger shovels and draglines, has
increased overall mine productivity. According to National Mining Association
data, overall coal mine productivity, measured in tons produced per miner shift,
increased 85% from 1990 to 2001.

Coal Regions

         Coal is mined from coalfields throughout the United States, with the
major production centers located in the Powder River Basin, Central Appalachia,
Northern Appalachia, the Illinois Basin and in other western coalfields. The
Company operates in the Central Appalachia region.

Powder River Basin

         The Powder River Basin contains some of the largest coal reserves in
the world. The Powder River Basin covers more than 12,000 square miles in
northeastern Wyoming and 7,000 square miles in southeastern Montana.
Demonstrated coal reserves total approximately 188 billion tons. Within the
Powder River Basin, there are various qualities of subbituminous coal, with
current production of subbituminous coal ranging from 8,300 Btu per pound to
9,200 Btu per pound and from 0.8% sulfur to 0.2% sulfur. The mines located just
north and south of Gillette, Wyoming are categorized as Southern Powder River
Basin mines. The coal in the Southern Powder River Basin is ranked as
subbituminous with an extremely low sulfur content.

                                      -10-
<PAGE>




         Production in the Southern Powder River Basin has increased from
approximately seven million tons in 1970 to approximately 360 million tons in
2002, and coal production in the Powder River Basin now accounts for
approximately 30% of U.S. coal consumption by volume. The Southern Powder River
Basin has grown into the largest coal supply region in the United States. From
1990 to 2000, the region's compounded annual production growth rate was 7%
compared to an overall compounded annual production growth rate of 0.5% for the
total U.S. coal industry. The Southern Powder River Basin markets more than 95%
of its coal to U.S. electricity generators, principally in this region between
the Rocky Mountains and the Appalachian Mountains.

Central / Southern Appalachia

         Central/Southern Appalachia contains coalfields in eastern Kentucky,
Tennessee, Alabama, southwestern Virginia and central and southern West
Virginia. Production in Central/Southern Appalachia has decreased from
approximately 305 million tons in 1996 to approximately 290 million tons in
2001. Production declined in all major sections of Central/Southern Appalachia
except for southern West Virginia, which has grown due to the expansion of more
economically attractive surface mines. The region has experienced significant
consolidation in the past several years due to modest demand growth and strong
competition from western coal. Central/Southern Appalachian operators market
approximately 67% of their coal to electric generators, principally in the
southeastern United States. Central/Southern Appalachia also sells extensively
to the export market and industrial customers. The coal of Central/Southern
Appalachia has an average heat content of 12,500 Btu per pound and generally has
low sulfur content.

Northern Appalachia

         High and medium sulfur coal is found in the Northern Appalachian
coalfields of western Pennsylvania, southeastern Ohio and northern West
Virginia. Demand for coal from this region has in recent years been and is
expected to remain relatively stable. Production in the region was approximately
143 million tons in 2001. Much of the production in this region is concentrated
in a few highly productive longwall mining operations in southeastern
Pennsylvania and northern West Virginia. Despite its sulfur content of 1.5% to
2.0%, which is considered medium sulfur coal, coal from the Pittsburgh seam
produced from these mines is considered attractive to electricity generators
because of its high heat content of approximately 13,000 Btu per pound.

Illinois Basin

         The Illinois Basin consists of approximately 48,000 square miles
throughout Illinois, southern Indiana and western Kentucky. There has been
significant consolidation among coal producers in the Illinois Basin over the
past several years. Production in the Illinois Basin peaked at 141 million tons
in 1990. Since 1990 and until recently, production had decreased by over 33% due
to displacement by lower sulfur, lower-cost coal. However, recently, production
in the Illinois Basin has stabilized. Illinois Basin coal is sold primarily to
local customers. Demonstrated reserves total an estimated 135 billion tons of
bituminous coal. Approximately 16 coal seams have been identified in this
region. Current production quality ranges from 9,000 to 12,700 Btu per pound and
0.8% to 4.5% sulfur, with production averaging approximately 11,400 Btu per
pound and 2.5% sulfur.

Western Bituminous Coal Regions

         The western bituminous coal regions include the Uinta Basin of
northwestern Colorado and Utah, the Four Corners Region in New Mexico and
Arizona and the Raton Basin in southern Colorado. These regions produce
high-quality, low sulfur steam coal for selected markets in these regions, for
export through west coast ports and for shipment to some midwestern customers.
Production in these regions has decreased from 104 million tons in 1996 to 103
million tons in 2001.

                                      -11-
<PAGE>




Lignite Production Regions

         Lignite is mined in Louisiana, Montana, North Dakota and Texas.

Coal Prices

         Coal prices vary dramatically by region and are determined by a number
of factors. The two principal components of the delivered price of coal are the
price of coal at the mine, which is influenced by mine operating costs and coal
quality, and the cost of transporting coal from the mine to the point of use.
Electric generators purchase coal on the basis of its delivered cost per million
Btu.

Price at the Mine

         The price of coal at the mine is influenced by geological
characteristics such as seam thickness, overburden ratios and depth of
underground reserves. Eastern U.S. coal is more expensive to mine than western
coal, because of thinner coal seams and thicker overburden. Underground mining,
prevalent in the eastern United States, has higher labor costs than surface
mining, including costs for labor benefits and health care, and high capital
costs, including modern mining equipment and construction of extensive
ventilation systems.

         In addition to the cost of mine operations, the price of coal at the
mine is also a function of quality characteristics such as heat value and
sulfur, ash and moisture content. Metallurgical coal has higher carbon and lower
ash content and is usually priced $4 to $10 per ton higher than steam coal
produced in the same regions. Higher prices are paid for special coking coal
with low volatility characteristics.

Transportation Costs

         Coal used for domestic consumption is generally sold freight on board
(FOB) at the mine, as described above, and the purchaser normally bears the
transportation costs. Export coal, however, is usually sold at the loading port,
and coal producers are responsible for shipment to the export coal-loading
facility and the buyer pays the ocean freight.

         Most electric generators arrange long-term shipping contracts with rail
or barge companies to assure stable delivered costs. Transportation can be a
large component of the buyer's cost. Although the customer pays the freight,
transportation cost is still important to coal mining companies because the
customer may choose a supplier largely based on the cost of transportation.
According to the National Mining Association, railroads account for nearly
two-thirds of total U.S. coal shipments. Trucks and overland conveyors haul coal
over shorter distances, while lake carriers and ocean vessels move coal to
export markets. Some domestic coal is shipped over the Great Lakes. Most coal
mines are served by a single rail company, but much of the Powder River Basin is
served by two competing rail carriers.

Cost of Electricity Generation

Cost Comparison of Fuel Types

         Coal prices at the mine, and transportation costs together constitute
coal's delivered price to customers. Coal attained its leading market share
because of its relative low cost and its availability throughout the United
States. The cost of fuel is the largest variable cost involved in electricity
generation. The delivered cost of coal to electric generators is relatively
stable as compared to the cost of natural gas and oil.

                                      -12-
<PAGE>




Generating Costs

         In addition to fuel, electric generators incur other variable and fixed
costs in electricity production. On average, the total cost per megawatt-hour of
coal-fueled electricity generation is less expensive than for electricity
generated from natural gas or nuclear power. According to Resource Data
International Inc., 20 of the 25 major electric generation plants with the
lowest operating costs in the United States in 2001 were coal-fueled.
Hydroelectric power is inexpensive but is limited geographically, and there are
few suitable sites for new hydroelectric dams. Moreover, because coal-fueled
electric generating plants, on average, are operating below maximum capacity,
these plants can increase their electricity generation without substantial
incremental capital costs, thus improving coal's overall cost competitiveness.
The following table illustrates the average cost of coal-fueled generation
relative to other electric generating sources.

Deregulation of the Electricity Generation Industry

         Congress enacted the Energy Policy Act of 1992 to stimulate competition
in electricity markets by giving wholesale suppliers access to the transmission
lines of U.S. electricity generators. In April 1996, the Federal Energy
Regulatory Commission (FERC) issued the first of a series of orders establishing
rules providing for open access to electricity transmission systems. The federal
government is currently exploring a number of options concerning utility
deregulation. Some individual states are also proceeding with their own
deregulation initiatives.

         The pace of deregulation differs significantly from state to state. As
of December 2002, 17 states and the District of Columbia had either enacted
legislation leading to the deregulation of the electricity market or issued a
regulatory order to implement retail access that would allow customers to choose
their own supplier of generation. Five states have delayed restructuring and 27
are not actively pursuing deregulation. In California, where supply and demand
imbalances created electricity supply shortages, the California Public Utilities
Commission suspended deregulation.

         A possible consequence of deregulation is downward pressure on fuel
prices. However, because of coal's cost advantage and because some coal-fueled
generating facilities are underutilized in the current regulated electricity
market, the Company believes that additional coal demand would arise as
electricity markets are deregulated if the most efficient coal-fueled power
plants are operated at greater capacity.

                               COMPANY OPERATIONS

         The Company is currently mining coal on a portion of its' New River
Tract. The Company has no long-term supply contracts at this time, and is
selling coal on the spot market, as well as through short-term contracts. The
Company is seeking to enter into long-term contracts, but there is no guarantee
that such contracts will be secured.

         The Company will need substantial additional capital to support its'
budget. The Company has a limited operating history and only began coal mining
activities in August 2003 when it commenced production from its mine # 2 surface
mine.

Areas of Interest

         The New River Tract assemblage of coal mineral rights owned by the
Company consists of approximately sixty-five thousand (65,000) acres that lie in
Anderson, Campbell and Scott Counties, Tennessee.

                                      -13-
<PAGE>




         There are six coal seams that are known to contain mineable coal, that
exceed twenty-eight inches in thickness under these mineral rights. The coal
seams that are twenty-eight inches in thickness or larger are virgin or have
been partially mined over the last hundred plus years on the New River Tract.
Several additional coal seams, which outcrop near the top of the mountains, have
been partially surfaced mined, but because of the limited amount of information
available, no determination of mineability can be made for these seams. The
Sewanee and Bon Air coal seams are present under the mineral rights but lie more
than a thousand feet below drainage.

         At the present time there are two separate areas located on the New
River Tract assemblage that are producing coal which include (1) a surface mine
situated in Devonia, Tennessee (Patterson Mountain), and (2) a portion of the
New River Tract mined by U.S. Coal, Inc., an independent mine operator that pays
royalties to the Company on coal production. The Company is currently working on
four additional permits to open mines and has been the process with the Office
of Surface Mining.

Location

         The Company's New River Tract mineral rights assemblage is located
approximately twenty-five miles northwest of Knoxville, Tennessee. Portions of
the mineral rights extend into Anderson, Campbell and Scott Counties, Tennessee.

Transportation

         Transportation facilities in the area of these mineral rights include
roads and rail. The road network includes Tennessee State Highway 116, which
crosses the mineral rights and several gravel and hard surface roads that
provide adequate access for any mining operations. Interstate Highways 75 and 40
are within a few miles of the property. All of the rail facilities are served by
the Norfolk Southern Railroad.

         In addition, there are two Tennessee Valley Authority ("TVA")
coal-fired steam plants within thirty miles of the area. The TVA-Kingston steam
plant and the TVA-Bull Run plant are located on good, hard surface roads that
are adequate for delivery of coal by truck.

Drilling Information

         Several mining companies have performed core drilling in the area. Over
seven hundred core holes are either located on the mineral rights property or
are close enough to the mineral rights property to provide reference
information.

Geology

         Known coal bearing strata on the property include coal beds from the
Crab Orchard and Crooked Fork groups, and the Slatestone, Indian Bluff, Graves
Gap, Red Oak Mountain, Vowell Mountain and Cross Mountain formations. Only coal
seams from the Blue Gem coal, located near the top of the Slatestone formation,
upwards occur on the New River Tract. Core drilling has indicated the existence
of coal as low as the Wilder coals, at the top of the Gizzard Group.

         The strata that are above the water drainage level consist mainly of
relatively thick shale and siltstone sequences with sandstone layers. Coal seams
occur in the shale sequences. There are six coal seams that are targets and all
of these seams are above the water drainage level. There are other coal seams
that contain coal, but insufficient information is available to estimate
mineability. The northern portion of the New River Tract property has not been
explored by core drilling, and could possibly contain a large amount of coal.

                                      -14-
<PAGE>




Railroad Loading Facilities

         There are railroad facilities located at Devonia, Tennessee, where
Tennessee Mining, Inc. (a division of Addington Enterprises, Inc.) was active
until the spring of 1998. Also railroad facilities are available at Smoky
Junction, Tennessee, where U.S. Coal, Inc. is presently operating one
underground mine on the Pewee Rider coal seam on Burge Mountain. A coal
processing facility is located at each of the above railroad facilities. The
Company, subject to availability of funds, intends to improve rail facilities
where necessary to serve its production needs.


          COAL SEAM DESCRIPTION ON COMPANY MINERAL RIGHTS IN TENNESSEE

         NOTE: The Company cannot now compute any "reserves" because only two of
its' properties are in a state of production. "Reserves", to be so classified,
must be based upon reasonably accurate scientific data and professional
analysis, be recoverable (economically and physically), have a permitted and
operating mine facility at the coal location, and be subject to current sales.
All of these criteria have not been met on the Company's mineral rights. The
Company has, however, estimated potential tonnages in its' mineral rights, based
upon information available to it and professional reports by a qualified
professional geologist for internal use only. Such internal tonnage estimates
should not be viewed as reserves because of the lack of criteria compliance
discussed above. The use of "potential coal" or "potential tons" is theoretical
and assumes both existence and mineability, of which there is no assurance.

Jellico Seam

         The Jellico (State) seam is located near the base of the Jellico
Formation in the Pennsylvanian Series. The elevation of the coal, in the Coon
Pool Branch area, is approximately 1550 feet. The rock strata dips to the
northwest at 0.5 to 1.0 percent.

         Topographic relief is relatively high (1800 to 1900 feet) with base
drainage levels of 1400 to 1500 feet elevation and mountain tops as high as
3350' in elevation. The area is drained by Coon Pool Branch, which flows east
into the New River.

         Eleven core holes were drilled in the area, with ten of the holes
showing coal of mineable thickness. The area consists of 514 acres of mineable
coal, of which 496 acres are considered measured and has 2,377,500 tons (in
place) with an additional 81,000 tons in the indicated category.

         West Coal Company, which mined the area in the early 1980's and prior
to Tennessee Mining, Inc., drilled the eleven drill holes, but no coal quality
analyses are available. Tennessee Mining, Inc. operated mines in the area from
1995 to early 1998, but did no core drilling in the area. The Jellico seam coal
has been mined extensively on the Company's property, including the Stallion
Branch mine immediately to the west of the area. The sulfur content of past
samples of coal from the Jellico seam ranged from 1.5 to 2.5%.

         It is unknown to what extent any of this coal is a mineable. Core
drilling was done in this area by West Coal Company, which mined the Jellico
seam on Cages Creek and on Smoky Creek, an area that lies west of the area mined
by the Company.

Windrock Seam

         The Windrock coal seam is the uppermost unit of the Graves Gap group,
and it lies approximately four hundred feet above the Jellico coal seam. Several
mines have operated this seam in Anderson and Campbell Counties, Tennessee, but
none on the New River Tract. The area contains 1,632 acres with the potential
for 7,834,704 tons based on information from more than eighty core holes that
were drilled by West Coal Company and Tennessee Mining, Inc.; however no mining
was done by either company, although a permit has been approved for underground
mining on Buffalo Mountain. It is unknown to what extent any of this is mineable
coal.

                                      -15-
<PAGE>




Big Mary Seam

         The Big Mary (Dean) seam lies approximately fifty feet above the
Windrock coal seam. Four areas are considered to contain mineable coal. This
coal is in the lower portion of the Red Oak Mountain Group. Three underground
mines that operated on the property show the following sulfur content.

o Moore mine at Devonia - sample taken in 1953 - 4.1% sulfur

o Trimore mine at
Devonia - sample taken in 1953 - 3.2% sulfur

o Alrosha mine on Bootjack Mt. - sample taken in 1976 - 2.5% sulfur

         The area on High Point contains 567 acres and 2,721,600 tons of
potential coal and another 42 acres with 201,600 tons of potential coal. The
core drilling in the area was done by West Coal Company in the 1980's. Tennessee
Mining, Inc. did not drill core holes that penetrated this seam in the area.

         High Point Mountain contains 395 acres and 2,133,000 tons of potential
coal and another 120 acres with 648,000 tons of potential coal. Only one core
hole has been drilled on this seam on High Point Mountain. The hole was drilled
by West Coal Company in the 1980's. The potentials were based on measurements
along the coal seam outcrop line where the coal was exposed. Tennessee Mining,
Inc. did not drill this area.

         Ash Log Mountain contains 593 acres and 3,024,300 potential tons and
another 83 acres with 423,300 potential tons of coal. Two core holes have been
drilled on the area, however a large potion of the outcrop line has been surface
mined, which indicates the coal is of mineable thickness. The outcrop line
measurements show thicker coal than the drill holes indicate. No quality
analyses are available for this area. Tennessee Mining, Inc. did not drill this
area.

     Red Oak Mountain  contains 421 acres and 2,399,700  tons of potential  coal
and another 34 acres and 193,800 tons of potential  coal. The core holes in this
area were drilled by Koppers,  Inc. and Anchor Oil Co.  Tennessee  Mining,  Inc.
drilled two holes in 1997 that are south of the area.

Walnut Mountain Seam

         The Walnut Mountain seam lies approximately three hundred fifty feet
above the Big Mary seam and forty feet below the Pewee seam. The coal is usually
less than 1% sulfur and has a high Btu content. The area on High Point contains
193 acres and 864,500 tons of potential coal in the measured category. Several
core holes have been drilled in the area. Tennessee Mining, Inc. drilled
twenty-one holes, with West Coal Company and Conrich Coal drilling the remaining
holes. The underground mine was mined by Scott Coal Corporation (owned by West
Coal Co.), and closed in the mid 1980's.

         The area on Buffalo Mountain contains 624 acres and 3,369,600 tons of
potential coal on the Walnut Mountain seam. More than thirty core holes have
been drilled in the area. The coal seams have partings (shale zones) in some of
the area and the coal will have to be processed (i.e. processed at a wash and
prep plant) before it can be marketed. This area is above the Windrock area on
Buffalo Mountain.

Pewee Seam

         The area of the Pewee seam on Fork Mountain contains approximately
1,372,000 tons of potential coal on 286 acres that remains unmined. At present,
a mine is permitted on this area. The mine can be re-opened in a short time -
usually 60 to 90 days. The mine is permitted as Reatta Mining, Fork Mtn. Mine
#1.

                                      -16-
<PAGE>




         The coal seam averages thirty inches in thickness and is a "low sulfur
product", with less than 1% sulfur content. The coal from the Pewee seam usually
can be sold without washing if mining conditions are favorable.

         There is an area on Stallion Mountain where the Pewee seam averages 33"
in thickness and has an area containing 486 acres and 2,405,700 tons of
potential coal in the measured category. The top of Stallion Mountain possibly
may allow mountain top surface mining.

Pewee Rider Seam

         The area on the High Point property contains 139 acres and 771,500 tons
of potential coal and another 8 acres and 44,400 tons of potential coal. The
Pewee Rider seam lies approximately forty feet above the Pewee coal seam and
eighty-five feet above the Walnut Mountain seam; however, in some areas the
interval can be much less. Twenty-one core holes were drilled by Tennessee
Mining, Inc. in 1995 on this seam.

         The area on the Hannah property contains 94 acres and 465,300 tons of
potential coal. This area is adjacent to the Reatta Mining #3 mine, and should
be underground mined. A surface mine is permitted and active to the north and
adjacent to the area.

ACREAGE AND COAL SEAMS FOUND IN THE NATIONAL COAL CORPORATION ASSEMBLAGE -
NEW RIVER TRACT
------------------------------------------------------------------------------

SEAM                   LOCATION                   MEASURED ACRES
====================== ========================== ====================

Jellico                Coon Pool Branch                           496
Jellico                Cage Creek                               1,230
Windrock               Buffalo Mountain                         1,632
Big Mary               High Point                                 567
Big Mary               High Point Mountain                        395
Big Mary               Ash Log Mountain                           593
Big Mary               Red Oak Mountain                           421
Walnut Mt.             High Point                                 193
Walnut Mt.             Buffalo Mountain                           624
Pewee                  Fork Mountain                              286
Pewee                  Stallion Mountain                          486
Pewee Rider            High Point                                 139
Pewee Rider            Burge Mountain                             380
Pewee Rider            Hannah Top                                  94

Backlog of Orders.  There are currently various orders for sales at this time.
-----------------

Government Contracts.  None at this time.
--------------------

                                      -17-

<PAGE>




                               REGULATORY MATTERS

         Federal, state and local authorities regulate the U.S. coal mining
industry with respect to matters such as employee health and safety, permitting
and licensing requirements, air quality standards, water pollution, plant and
wildlife protection, the reclamation and restoration of mining properties after
mining has been completed, the discharge of materials into the environment,
surface subsidence from underground mining and the effects of mining on
groundwater quality and availability. In addition, the industry is affected by
significant legislation mandating certain benefits for current and retired coal
miners. Numerous federal, state and local governmental permits and approvals are
required for mining operations. The Company believes that it has obtained all
permits currently required to conduct its present mining operations. The Company
may be required to prepare and present to federal, state or local authorities
data pertaining to the effect or impact that a proposed exploration for, or
production of, coal may have on the environment. These requirements could prove
costly and time-consuming, and could delay commencing or continuing exploration
or production operations. Future legislation and administrative regulations may
emphasize the protection of the environment and, as a consequence, the Company's
activities may be more closely regulated. Such legislation and regulations, as
well as future interpretations and more rigorous enforcement of existing laws,
may require substantial increases in equipment and operating costs to the
Company and delays, interruptions or a termination of operations, the extent of
which cannot be predicted.

         The Company endeavors to conduct its mining operations in compliance
with all applicable federal, state and local laws and regulations. However,
because of extensive and comprehensive regulatory requirements, violations
during mining operations occur from time to time in the industry. None of the
violations to date or the monetary penalties assessed upon the Company have been
material.

Mine Safety and Health

         Stringent health and safety standards have been in effect since
Congress enacted the Coal Mine Health and Safety Act of 1969. The Federal Mine
Safety and Health Act of 1977 significantly expanded the enforcement of safety
and health standards and imposed safety and health standards on all aspects of
mining operations.

         Most of the states, including the state of Tennessee in which the
Company operates, have state programs for mine safety and health regulation and
enforcement. Collectively, federal and state safety and health regulation in the
coal mining industry is perhaps the most comprehensive and pervasive system for
protection of employee health and safety affecting any segment of U.S. industry.
While regulation has a significant effect on operating costs of the Company,
U.S. competitors of the Company are subject to the same degree of regulation.

Environmental Laws

         The Company is subject to various federal, state and foreign
environmental laws. Some of these laws, discussed below, place many requirements
on coal mining operations. Federal and state regulations require regular
monitoring of the Company's mines and other facilities to ensure compliance.

Surface Mining Control and Reclamation Act

         The Surface Mining Control and Reclamation Act of 1977 (SMCRA), which
is administered by the Department of the Interior's Office of Surface Mining
Reclamation and Enforcement (OSM), establishes mining, environmental protection
and reclamation standards for all aspects of surface mining as well as many
aspects of deep mining. Mine operators must obtain SMCRA permits and permit
renewals for mining operations from the OSM. Where state regulatory agencies
have adopted federal mining programs under the act, the state becomes the
regulatory authority.

                                      -18-
<PAGE>




         SMCRA permit provisions include requirements for coal prospecting; mine
plan development; topsoil removal, storage and replacement; selective handling
of overburden materials; mine pit backfilling and grading; protection of the
hydrologic balance; subsidence control for underground mines; surface drainage
control; mine drainage and mine discharge control and treatment; and
re-vegetation.

         The mining permit application process is initiated by collecting
baseline data to adequately characterize the pre-mine environmental condition of
the permit area. This work includes surveys of cultural resources, soils,
vegetation, wildlife, assessment of surface and ground water hydrology,
climatology and wetlands. In conducting this work, the Company collects geologic
data to define and model the soil and rock structures and coal that is to be
mined. The Company develops mine and reclamation plans by utilizing this
geologic data and incorporating elements of the environmental data. The mine and
reclamation plan incorporates the provisions of SMCRA, the state programs and
the complementary environmental programs that impact coal mining. Also included
in the permit application are documents defining ownership and agreements
pertaining to coal, minerals, oil and gas, water rights, rights of way and
surface land and documents required of the OSM's Applicant Violator System.

         Once a permit application is prepared and submitted to the regulatory
agency, it goes through a completeness review and technical review. Public
notice of the proposed permit is given for a comment period before a permit can
be issued. Some SMCRA mine permits take over a year to prepare, depending on the
size and complexity of the mine and often take six months to two years to be
issued. Regulatory authorities have considerable discretion in the timing of the
permit issuance and the public has rights to comment on and otherwise engage in
the permitting process, including through intervention in the courts.

         Before a SMCRA permit is issued, a mine operator must submit a bond or
otherwise secure the performance of reclamation obligations. The Abandoned Mine
Land Fund, which is part of SMCRA, requires a fee on all coal produced. The
proceeds are used to reclaim mine lands closed prior to 1977 and to pay health
care benefit costs of orphan beneficiaries of the Combined Fund. The fee, which
partially expires on September 30, 2004, is $0.35 per ton on surface-mined coal
and $0.15 per ton on deep-mined coal. After that date, a fee will be assessed
each year to cover the expected health care benefit costs of the orphan
beneficiaries. The Company is current on all Abandoned Mine Land Fund payments.

         SMCRA stipulates compliance with many other major environmental
programs. These programs include the Clean Air Act; Clean Water Act; Resource
Conservation and Recovery Act (RCRA); Comprehensive Environmental Response,
Compensation, and Liability Acts (CERCLA) superfund and employee right-to-know
provisions. Besides OSM, other Federal regulatory agencies are involved in
monitoring or permitting specific aspects of mining operations. The U.S.
Environmental Protection Agency (EPA) is the lead agency for States or Tribes
with no authorized programs under the Clean Water Act, RCRA and CERCLA. The U.S.
Army Corps of Engineers (COE) regulates activities affecting navigable waters
and the U.S. Bureau of Alcohol, Tobacco and Firearms (ATF) regulates the use of
explosive blasting.

         The Company does not believe there are any substantial matters that
pose a risk to maintaining its existing mining permits or hinder its ability to
acquire future mining permits. It is Company policy to comply with all
requirements of the Surface Mining Control and Reclamation Act and the state
laws and regulations governing mine reclamation.

Clean Air Act

         The Clean Air Act, the Clean Air Act Amendments and the corresponding
state laws that regulate the emissions of materials into the air, affect coal
mining operations both directly and indirectly. Direct impacts on coal mining
and processing operations may occur through Clean Air Act permitting
requirements and/or emission control requirements relating to particulate
matter, such as fugitive dust, including future regulation of fine particulate
matter measuring 10 micrometers in diameter or smaller. The Clean Air Act
indirectly affects coal mining operations by extensively regulating the air
emissions of sulfur dioxide, nitrogen oxides, mercury and other compounds
emitted by coal-fueled electricity generating plants.

                                      -19-
<PAGE>




         In July 1997, the EPA adopted new, more stringent National Ambient Air
Quality Standards for very fine particulate matter and ozone. As a result, some
states will be required to change their existing implementation plans to attain
and maintain compliance with the new air quality standards. The Company's mining
operations and electricity generating customers are likely to be directly
affected when the revisions to the air quality standards are implemented by the
states. State and federal regulations relating to implementation of the new air
quality standards may restrict the Company's ability to develop new mines or
could require the Company to modify its existing operations. The extent of the
potential direct impact of the new air quality standards on the coal industry
will depend on the policies and control strategies associated with the state
implementation process under the Clean Air Act, but could have a material
adverse effect on the Company's financial condition and results of operations.

         Title IV of the Clean Air Act Amendments places limits on sulfur
dioxide emissions from electric power generation plants. The limits set baseline
emission standards for these facilities. Reductions in emissions occurred in
Phase I in 1995 and in Phase II in 2000 and apply to all coal-fueled power
plants. The affected electricity generators have been able to meet these
requirements by, among other ways, switching to lower sulfur fuels, installing
pollution control devices, such as flue gas desulfurization systems, which are
known as "scrubbers," reducing electricity generating levels or purchasing
sulfur dioxide emission allowances. Emission sources receive these sulfur
dioxide emission allowances, which can be traded or sold to allow other units to
emit higher levels of sulfur dioxide. The Company cannot accurately predict the
effect of these provisions of the Clean Air Act Amendments on it in future
years. At this time, the Company believes that implementation of Phase II has
resulted in an upward pressure on the price of lower sulfur coals, as additional
coal-fueled electricity generating plants have complied with the restrictions of
Title IV.

         The Clean Air Act Amendments also require electricity generators that
currently are major sources of nitrogen oxides in moderate or higher ozone
non-attainment areas to install reasonably available control technology for
nitrogen oxides, which are precursors of ozone. In addition, the EPA promulgated
the final rules that would require coal-burning power plants in 19 eastern
states and Washington, D.C. to make substantial reductions in nitrogen oxide
emissions beginning in May 2004. Installation of additional control measures
required under the final rules will make it more costly to operate coal-fueled
electricity generating plants.

         The Clean Air Act Amendments provisions for new source review require
electricity generators to install the best available control technology if they
make a major modification to a facility that results in an increase in its
potential to emit regulated pollutants. From 1990 to 1999, the EPA interpreted
the new source review criteria in a relatively consistent manner; however, the
EPA changed their interpretation during 1999. The Justice Department, on behalf
of the EPA, filed a number of lawsuits since November 1999, alleging that 10
electricity generators violated the new source review provisions of the Clean
Air Act Amendments at power plants in the Midwestern and Southern United States.
The EPA issued an administrative order alleging similar violations by the
Tennessee Valley Authority, affecting seven plants and notices of violation for
an additional eight plants owned by the affected electricity generators. Many
electricity generators have announced settlements with the Justice Department
requiring the installation of additional control equipment on selected
generating units. If the remaining electricity generators are found to be in
violation, they could be subject to civil penalties and be required to install
the required control equipment or cease operations. The Company's customers are
among the named electricity generators and if found not to be in compliance, or
as a result of the settlements, the fines and requirements to install additional
control equipment could adversely affect the amount of coal they would burn if
the plant operating costs were to increase to the point that the plants were
operated less frequently. At the end of 2002, the EPA issued proposed new source
review rules for sources that include electricity generators. These new rules
define routine maintenance, repair and replacement. If these rules are finalized
without material revisions, electricity generators should be better able to make
needed repairs and improvements to their plants without the uncertainty of
triggering cost-prohibitive environmental rules.

                                      -20-

<PAGE>




         The Clean Air Act Amendments set a national goal for the prevention of
any future, and the remedying of any existing, impairment of visibility in 156
national parks and wildlife areas across the country. Under regulations issued
by the EPA in 1999, states are required to set a goal of restoring natural
visibility conditions in these Class I areas in their states by 2064 and to
explain their reasons to the extent they determine that this goal cannot be met.
The state plans may require the application of "Best Available Retrofit
Technology" after 2010 on sources found to be contributing to visibility
impairment of regional haze in these areas. The control technology requirements
could cause customers of the Company to install equipment to control sulfur
dioxide and nitrogen oxide emissions. The requirement to install control
equipment could affect the amount of coal supplied to those customers if they
decide to switch to other sources of fuel to lower emission of sulfur dioxides
and nitrogen oxides, which may have a material adverse affect on the Company.

         The Clean Air Act Amendments require a study of electricity generating
plant emissions of certain toxic substances, including mercury, and direct the
EPA to regulate these substances, if warranted. In December 2000, the EPA
decided that mercury air emissions from power plants should be regulated. The
Company expects that the EPA will propose regulations in 2004 and will issue
final regulations perhaps nine months thereafter. It is possible that future
regulatory activity may seek to reduce mercury emissions and these requirements,
if adopted, could result in reduced use of coal if electricity generators switch
to other sources of fuel.

         In addition, Vice President Cheney, as the head of the National Energy
Policy Development Group, submitted to the President a National Energy Policy
which recommended, among other things, that the President direct the EPA
Administrator to work with Congress to propose legislation that would
significantly reduce and cap emissions of sulfur dioxide, nitrogen oxide and
mercury from electricity power generators. In February 2002, the President
proposed to cut electricity power generator emissions by approximately 70% by
2018 using a cap and trade system similar to that now in effect for acid
deposition control. The President's proposal has been translated into a
legislative proposal. In addition, similar emission reduction proposals have
been introduced in Congress, some of which propose to regulate the three
pollutants and carbon dioxide, but no such legislation has passed either house
of the Congress. If this type of legislation were enacted into law, it could
impact the amount of coal supplied to those electricity-generating customers if
they decide to switch to other sources of fuel whose use would result in lower
emission of sulfur dioxides, nitrogen oxides, mercury and carbon dioxide, all of
which may have an adverse material affect on the Company.

         In February 2003, a number of states notified the EPA that they plan to
sue the agency to force it to set new source performance standards for utility
emissions of carbon dioxide and to tighten existing standards for sulfur dioxide
and particulate matter for utility emissions. In June 2003, Massachusetts,
Connecticut and Maine filed a lawsuit against the EPA seeking a court order
requiring the EPA to designate carbon dioxide as a criteria pollutant. If these
states are successful in obtaining a court order and the EPA agrees to set
emission limitations for carbon dioxide, it could adversely affect the amount of
coal customers would purchase from the Company.

Clean Water Act

         The Clean Water Act of 1972 affects coal-mining operations by
establishing in-stream water quality standards and treatment standards for
wastewater discharge through the National Pollutant Discharge Elimination System
(NPDES). Regular monitoring, reporting requirements and performance standards
are requirements of NPDES permits that govern the discharge of pollutants into
water.
         Total Maximum Daily Load (TMDL) regulations established a process by
which states designate stream segments as impaired (not meeting present water
quality standards). Industrial dischargers, including coal mines, will be
required to meet new TMDL effluent standards for these stream segments. The
adoption of new TMDL effluent limitations for the Company's coal mines could
require more costly water treatment and could adversely affect coal production
of the Company.

                                      -21-
<PAGE>




         States are also adopting anti-degradation regulations in which a state
designates certain water bodies or streams as "high quality." These regulations
would prohibit the diminution of water quality in these streams. Waters
discharged from coal mines to high quality streams will be required to meet or
exceed new "high quality" standards. The designation of high quality streams at
the Company's coal mines could require more costly water treatment and could
aversely affect the Company's coal production.

Resource Conservation and Recovery Act

         The Resource Conservation and Recovery Act (RCRA), which was enacted in
1976, affects coal mining operations by establishing requirements for the
treatment, storage and disposal of hazardous wastes. Coal mine wastes, such as
overburden and coal cleaning wastes, are exempted from hazardous waste
management.

         Subtitle C of RCRA exempted fossil fuel combustion wastes from
hazardous waste regulation until the EPA completed a report to Congress and made
a determination on whether the wastes should be regulated as hazardous. In a
1993 regulatory determination, the EPA addressed some high volume-low toxicity
coal combustion wastes generated at electric utility and independent power
producing facilities. In May 2000, the EPA concluded that coal combustion wastes
do not warrant regulation as hazardous under RCRA. The EPA is retaining the
hazardous waste exemption for these wastes. However, the EPA has determined that
national non-hazardous waste regulations under RCRA Subtitle D are needed for
coal combustion wastes disposed in surface impoundments and landfills and used
as mine-fill. The agency also concluded beneficial uses of these wastes, other
than for mine filling, pose no significant risk and no additional national
regulations are needed. As long as this exemption remains in effect, it is not
anticipated that regulation of coal combustion waste will have any material
effect on the amount of coal used by electricity generators.

Federal and State Superfund Statutes

         Superfund and similar state laws affect coal mining and hard rock
operations by creating a liability for investigation and remediation in response
to releases of hazardous substances into the environment and for damages to
natural resources. Under Superfund, joint and several liabilities may be imposed
on waste generators, site owners or operators and others regardless of fault.

Global Climate Change

         The United States, Australia and more than 160 other nations are
signatories to the 1992 Framework Convention on Climate Change, which is
intended to limit emissions of greenhouse gases, such as carbon dioxide. In
December 1997, in Kyoto, Japan, the signatories to the convention established a
binding set of emission targets for developed nations. Although the specific
emission targets vary from country to country, the United States would be
required to reduce emissions to 93% of 1990 levels over a five-year budget
period from 2008 through 2012. Although the United States has not ratified the
emission targets and no comprehensive regulations focusing on greenhouse gas
emissions are in place, these restrictions, whether through ratification of the
emission targets or other efforts to stabilize or reduce greenhouse gas
emissions, could adversely affect the price and demand for coal. According to
the Energy Information Administration's Emissions of Greenhouse Gases in the
United States 2001, coal accounts for 32% of greenhouse gas emissions in the
United States, and efforts to control greenhouse gas emissions could result in
reduced use of coal if electricity generators switch to lower carbon sources of
fuel. In March 2001, President Bush reiterated his opposition to the Kyoto
Protocol and further stated that he did not believe that the government should
impose mandatory carbon dioxide emission reductions on power plants. In February
2002, President Bush announced a new approach to climate change, confirming the
Administration's opposition to the Kyoto Protocol and proposing voluntary
actions to reduce the greenhouse gas intensity of the United States. Greenhouse
gas intensity measures the ratio of greenhouse gas emissions, such as carbon
dioxide, to economic output. The President's climate change initiative calls for
a reduction in greenhouse gas intensity over the next 10 years which is
approximately equivalent to the reduction that has occurred over each of the
past two decades.

                                      -22-
<PAGE>




Permitting

         Mining companies must obtain numerous permits that impose strict
regulations on various environmental and safety matters in connection with coal
mining. These provisions include requirements for coal prospecting; mine plan
development; topsoil removal, storage and replacement; selective handling of
overburden materials; mine pit backfilling and grading; protection of the
hydrologic balance; subsidence control for underground mines; surface drainage
control; mine drainage and mine discharge control and treatment; and
revegetation.

         The Company must obtain permits from applicable state regulatory
authorities before it begins to mine reserves. The mining permit application
process is initiated by collecting baseline data to adequately characterize the
pre-mine environmental condition of the permit area. This work includes surveys
of cultural resources, soils, vegetation, wildlife, assessment of surface and
ground water hydrology, climatology and wetlands. In conducting this work, the
Company collects geologic data to define and model the soil and rock structures
and coal that will be mined. The Company develops mine and reclamation plans by
utilizing this geologic data and incorporating elements of the environmental
data. The mine and reclamation plan incorporates the provisions of the Surface
Mining Control and Reclamation Act, the state programs and the complementary
environmental programs that impact coal mining. Also included in the permit
application are documents defining ownership and agreements pertaining to coal,
minerals, oil and gas, water rights, rights of way, and surface land and
documents required of the Office of Surface Mining's Applicant Violator System.

         Once a permit application is prepared and submitted to the regulatory
agency, it goes through a completeness review, technical review and public
notice and comment period before it can be approved. Some Surface Mining Control
and Reclamation Act mine permits can take over a year to prepare, depending on
the size and complexity of the mine and often take six months to sometimes two
years to receive approval. Regulatory authorities have considerable discretion
in the timing of the permit issuance and the public has rights to comment on and
otherwise engage in the permitting process, including through intervention in
the courts.

         The Company does not believe there are any substantial matters that
pose a risk to maintaining its existing mining permits or hinder its ability to
acquire future mining permits (except availability of cash for bond deposits).
It is the Company's policy to ensure that its operations are in full compliance
with the requirements of the Surface Mining Control and Reclamation Act and the
state laws and regulations governing mine reclamation.

                                    EMPLOYEES

         At December 31, 2003, the Company had 26 full-time employees, of which
20 were engaged in direct mining operations, 2 in mining supervision, and 4 in
executive management and legal administration. None of the Company's employees
are covered by a collective bargaining agreement. The Company considers its
relationship with its employees to be favorable. The Company currently utilizes
the services of 3 independent consultants: 1 in research, 1 in accounting, and 1
in security. The 20 miners and 2 supervisors are based in Devonia, Tennessee;
the Chief Executive Officer/President, the Chief Financial Officer and the
General Counsel are based in Knoxville, Tennessee. The Chairman is based in
Houston, Texas.

Item 2.       Description of Properties

         The Company's executive offices are located at 319 Ebenezer Road,
Knoxville, TN 37923; the telephone number is (865) 769-3749 and the facsimile
number is (865) 769-3759. The Company leases corporate office space), at a
monthly cost of $1,800, with a lease term which expires in September 2004. The
Company's base of operations for its mining activities is located in Devonia,
Tennessee. The Company also leases space outside Atlanta, Georgia on a
month-to-month basis at a cost of $600 per month, to house its web servers and
financial data computers. The Company also leases storage space in eastern
Tennessee to house its maps and other geological data.


                                      -23-
<PAGE>





Item 3.       Legal Proceedings

         The Company is not involved in any litigation.



Item 4.       Submission of Matters to a Vote of Security Holders

         None.


                                      -24-
<PAGE>



                                     PART II

Item 5.       Market for Common Equity and Related Stockholder Matters

Common Stock

         Our Common Stock trades in the Over The Counter market, through the
quotation medium commonly referred to as the "Pink Sheets," under the symbol
"NLCP.PK." The following table sets forth, for the periods indicated, the high
and low sales prices for our Common Stock:
<TABLE>
<CAPTION>
<S>                                                                                   <C>            <C>

                                                                                        High           Low
                                                                                        ----           ---
             Year Ended December 31, 2002
                  First Quarter.............................................          $  0.60        $   0.50
                  Second Quarter............................................                 *              *
                  Third Quarter.............................................                 *              *
                  Fourth Quarter............................................                 *              *

</TABLE>

         *There is no reliable information available for these quotes due to the
inactivity of the stock during this period.
<TABLE>
<CAPTION>
<S>                                                                                   <C>            <C>

                                                                                        High           Low
                                                                                        ----           ---
             Year Ended December 31, 2003
                  First Quarter.............................................          $  0.60        $   0.50
                  Second Quarter............................................             0.60            0.50
                  Third Quarter.............................................             0.51            0.45
                  Fourth Quarter............................................             0.51            0.35
</TABLE>

         On March 17, 2004, the closing sales price of the Common Stock as
reported on the Pink Sheets was $1.28 per share. As of March 17, 2003, there
were 89 holders of record of our Common Stock.

Dividends

         We have never paid any dividends on our Common Stock. We intend to
retain any earnings for use in our business and do not intend to pay any cash
dividends on our Common Stock in the foreseeable future.

Equity Compensation Plan Information

         The following table sets forth certain information regarding our equity
compensation plans as of December 31, 2003.
<TABLE>
<CAPTION>
<S>                        <C>                           <C>                            <C>

                            Number of securities to                                         Number of securities
                            be issued upon exercise      Weighted-average exercise         remaining available for
                            of outstanding warrants         price of outstanding        future issuance under equity
                                  and rights                warrants and rights              compensation plans
-----------------------    --------------------------    ---------------------------    ------------------------------

Equity compensation
plans not approved by
shareholders                  1,762,250                         $ 0.5547                           --
----------------------- -- -------------------------- -- --------------------------- -- ------------------------------

</TABLE>

Material  Features  of  Individual  Equity  Compensation  Plans not  Approved by
Stockholders

         In March 2003, we issued to The Webb Group warrants to purchase up to
1,597,250 shares of our common stock at an exercise price of $0.55 per share as
consideration for the issuance of two notes payable. At the time of issuance,
this exercise price was at a premium to the price per share as quoted on the
Pink Sheets. The warrants have a term of 2 years. These warrants were
subsequently purchase by Crestview Capital Master, LLC directly from The Webb
Group in February 2004.

         In November 2003, we issued to an unrelated third party warrants to
purchase up to 45,833 shares of our common stock at an exercise price of $0.60
per share as consideration for the extension of the maturity date of a note
payable. The warrants have a term of 2 years.

         In November 2003, we issued to an unrelated third party warrants to
purchase up to 27,500 shares of our common stock at an exercise price of $0.60
per share as consideration for the extension of the maturity date of a note
payable. The warrants have a term of 2 years.

         In November 2003, we issued to an unrelated third party warrants to
purchase up to 41,667 shares of our common stock at an exercise price of $0.60
per share as consideration for the extension of the maturity date of a note
payable. The warrants have a term of 2 years.

         In November 2003, we issued to an unrelated third party warrants to
purchase up to 50,000 shares of our common stock at an exercise price of $0.60
per share as consideration for the extension of the maturity date of a note
payable. The warrants have a term of 2 years.

         In March 2004, the Chairman agreed to reduce his annual base salary to
$36,000. This agreement was entered into as a result of the Chairman taking a
much less active role in the day-to-day operations of the Company. Concurrent
with this reduction in annual base salary, the Chairman, who had been accruing
his salary since October 2003, agreed to receive all previously accrued salary
in stock, using a price per share of $0.55. This resulted in the issuance of
167,832 shares to the Chairman in March 2004.

                                      -25-

<PAGE>



Item 6.    Management's Discussion and Analysis of Financial Condition and
           Results of Operations

         No operations were conducted and no operating revenue was realized from
January 30, 2003 to June 30, 2003. From January 30, 2003 through June 30, 2003,
the Company's activities consisted of strategic, organizational, property
acquisition and financing matters. During the calendar third quarter 2003,
production commenced and accordingly, the Company is no longer considered to be
in the exploration stage. As of December 31, 2003, the Company was totally
illiquid and needed cash infusions from shareholders to provide capital, or
needed loans from any sources available. At December 31, 2003, the Company had
negative working capital of approximately $5,512,000 and a stockholders'
deficiency of approximately $2,927,000. These factors raise substantial doubt
about the Company's ability to continue as a going concern.

         The principal activity of the Company is coal mining. The Company
currently owns, in fee simple, the coal mineral rights to the New River Tract
assemblage, which consists of approximately sixty-five thousand (65,000) acres
that lie in Anderson, Campbell and Scott Counties, approximately twenty-five
miles northwest of Knoxville, Tennessee. These mineral rights revert back to the
surface owner on June 5, 2093. At the present time there are two separate areas
located on the New River Tract assemblage that are producing coal which include
(1) a surface mine situated in Devonia, Tennessee (Patterson Mountain), and (2)
a portion of the New River Tract mined by U.S. Coal, Inc., an independent mine
operator that pays royalties to the Company on its' coal production.

         The Company engages in coal production by locating, assembling,
leasing, assessing, permitting and developing coal properties in Eastern
Tennessee. The Company, after obtaining permits from the U.S. Department of the
Interior, mines said properties or contracts with independent mine operators for
extraction of the coal minerals on a negotiated fee basis. Some contracts may be
on a per ton basis, and some may be on a cost plus basis. The variance is
usually due to varying extraction conditions and circumstances. Reclamation
bonds are obtained and maintained by the Company for each producing property.
Bonds typically take the form of cash deposits with the U.S. Department of the
Interior, Office of Surface Mining. In theory, insurance bonds could be used,
but such are extremely difficult and time consuming for small companies to
obtain in the market.

         The Company currently sells its' production into the spot market and/or
based on short-term contracts, but in the future intends to seek long-term
supply contracts. No such long-term contracts have been negotiated to date.

         Many of the Company's properties have been subject to limited
production in the past. Some of the properties were abandoned by previous
producers due to poor market conditions, uneconomical production, high labor
costs and difficulty in securing reclamation bonds.

         The Company is required to obtain reclamation bonds for each producing
property. Bonds typically take the form of cash deposits with the U.S.
Department of the Interior, Office of Surface Mining. In theory, insurance bonds
could be used, but such are extremely difficult and time consuming for small
companies to obtain.

         The Company maintains an umbrella liability insurance policy for all of
its operations, and requires liability policies to be furnished by contract
operators, naming the Company as a co-insured.

         The coal industry in the past has been highly competitive, with very
thin margins in recent years. Only in the past two years, in the opinion of
management, have the economics begun to look favorable to coal again. This
situation is due, in part, to the surge in prices of natural gas. The price
increases of natural gas, on a Btu basis, have reached the point that coal fired
power plants, using the latest clean air compliant scrubber technology can be
price competitive with natural gas fired plants.

                                      -26-
<PAGE>




         The Company intends to exploit its' mineral rights by opening mines, as
its capital will allow, but it can only open a mine with an estimated $500,000
to $750,000 per mine, including bonds or cash deposited. Due to the operating
capital constraints, if the Company cannot raise such needed additional amounts
by loans or private placements, it will prevent the Company from expanding its'
mining operations beyond the current operations.

         NOTE: The Company cannot now compute any "reserves" because only one of
its' properties is in production. "Reserves", to be so classified, must be based
upon reasonably accurate scientific data and professional analysis, be
recoverable (economically and physically), have a permitted and operating mine
facility at the coal location, and be subject to current sales. All of these
criteria have not been met on the Company's mineral rights. The Company has,
however, estimated potential tonnages in its mineral rights, based upon
information available to it and professional reports by a qualified professional
geologist, for internal use only.

Significant Accounting Policies and Estimates

         The discussion and analysis of the Company's financial condition and
results of operations are based upon its' consolidated financial statements,
which have been prepared in accordance with accounting principles generally
accepted in the United States. The preparation of these financial statements
requires the Company to make estimates and judgments that affect the reported
amounts of assets, liabilities, revenues and expenses, and related disclosure of
contingent assets and liabilities. On an on-going basis, the Company evaluates
its' estimates, including those related to computing depreciation, depletion,
amortization, reclamation, asset impairment, valuation of non-cash transactions
and recovery of receivables. Estimates are then based on historical experience
and on various other assumptions that are believed to be reasonable under the
circumstances, the results of which form the basis for making judgments about
the carrying values of assets and liabilities that are not readily apparent from
other sources. Actual results may differ from these estimates under different
assumptions or conditions. The Company's use of estimates, however, is quite
limited, as it has adequate time to process and record actual results from
operations.

         Significant accounting policies are described in Note 2 to the
consolidated financial statements included in Item 7 of this Form 10-KSB. The
Company believes its' most critical accounting policies include revenue
recognition, the corresponding accounts receivable and the methods of estimating
depletion and accretion expense of actual mining operations in relation to
estimated total mineable tonnage on its' New River Tract property. The Company
believes the following accounting policies affect its' more significant
judgments and estimates used in preparation of its' consolidated financial
statements.

Revenue Recognition

         Under SEC Staff Accounting Bulletin No. 101, "Revenue Recognition in
Financial Statements," the Company recognizes revenue when all of the following
criteria are met: (1) persuasive evidence of an arrangement exists, (2) delivery
has occurred or services have been rendered, (3) the seller's price to the buyer
is fixed or determinable, and (4) collectibility is reasonably assured. In the
case of the Company's product, a price is negotiated with each customer with
specifics for requirements, a fixed price per ton, a delivery schedule, and
terms for payment. Unless cash is paid in advance, accounts receivables are
recorded as revenue is earned. The Company regularly evaluates the
collectibility of its' receivables based on a combination of factors. To date,
the Company has not had any customer whose payment was considered past due, and
as such has not had to record any reserves for doubtful collectibility.

                                      -27-
<PAGE>




Asset Retirement Obligation

         The Company's asset retirement obligations arise from the federal
Surface Mining Control and Reclamation Act of 1977 and similar state statutes,
which require that mine property be restored in accordance with specified
standards and an approved reclamation plan. Significant reclamation activities
include reclaiming refuse and slurry ponds, reclaiming the pit and support
acreage at surface mines, and sealing portals at deep mines. Reclamation
activities that are performed outside of the normal mining process are accounted
for as asset retirement obligations in accordance with the provisions of SFAS
143. The Company records its reclamation obligations on a mine-by-mine basis
based upon current permit requirements and estimated reclamation obligations for
such mines as determined by the Office of Surface Mining when the Company, prior
to the Company commencing its' mining operations under each permit, posts a
predetermined amount of reclamation bonds. The Office of Surface Mining's
estimates of disturbed acreage are determined based on approved mining plans and
related engineering data. Cost estimates are based upon estimates prepared by
the OSM based on historical costs. In accordance with the provisions of SFAS
143, the Company determines the fair value of its asset retirement obligations.
In order to determine fair value, the Company also estimates a discount rate, as
discussed further below:

         Discount rate -- SFAS 143 requires that asset retirement obligations be
         recorded at fair value. In accordance with the provisions of SFAS 143,
         the Company utilized a discounted cash flow technique to estimate the
         fair value of its obligations. The Company bases its discount rate on
         the rates of treasury bonds with maturities similar to expected mine
         lives, adjusted for its credit standing.

         On at least an annual basis, the Company reviews its entire reclamation
liability and makes necessary adjustments for permit changes as granted by state
authorities, additional costs resulting from accelerated mine closures, and/or
revisions to cost estimates and productivity assumptions, to reflect current
experience. At December 31, 2003, the Company had recorded asset retirement
obligation liabilities of $64,400. While the precise amount of these future
costs cannot be determined with certainty, as of December 31, 2003, the Company
estimates that the aggregate undiscounted cost of final mine closure is
approximately $257,500.

RESULTS OF  OPERATIONS  FOR THE PERIOD  FROM  JANUARY  30,  2003  (INCEPTION  OF
NATIONAL COAL CORPORATION) TO DECEMBER 31, 2003

         Since the formation of National Coal Corporation on January 30, 2003,
it had been deemed to be in the exploration stage because the Company did not
have any direct coal mining operations or proven reserves. However, during the
three-month period ended September 30, 2003, production commenced and
accordingly, the Company is no longer considered to be in the exploration stage.

         For the eleven months ended December 31, 2003, the Company had revenues
of $1,190,600 consisting of coal sales of $1,012,500 and royalty receipts of
$178,100, and a net loss of $3,332,900 primarily due to mine operations and
selling expenses of $1,657,600, exploration and development expenses of $80,400,
and general and administrative expenses of $1,871,400. The Company also incurred
$372,400 of interest expense related primarily to the issuance of notes payable,
and $366,600 of amortization expense related to the amortization of loan
acquisition costs.

Revenue

         For the eleven-month period ended December 31, 2003, the Company's coal
sales revenue resulted from the sale of a total of 35,125 tons of coal at an
average price per ton of approximately $28.83. The Company's top three customers
accounted for over 93% of total sales, with its' top customer representing
51.8%; its' second highest customer representing 26.8%; and its' third top
customer representing 14.6%. The sales to both the #1 and #3 customers were
conducted on a spot price basis, and the sales to 2nd highest customer was
pursuant to multiple short-term sales contracts.

                                      -28-
<PAGE>




Cost of Mining Operations and Selling Expenses

         For the eleven-month period ended December 31, 2003, the Company
incurred direct cost of mining operations and selling expenses of $1,657,600.
These expenses consisted primarily of (1) salary, benefits and other
compensation costs paid directly to miners of $431,300; (2) direct costs paid to
third party vendors whose goods and services were directly used in the process
of producing coal, such as equipment leases and maintenance expenses ($470,400),
blasting ($158,800), fuel ($191,300), parts and supplies ($227,200), hauling
costs ($65,700); and (3) selling commissions of $5,100.

Exploration and Development Expenses

         For the eleven-month period ended December 31, 2003, the Company
incurred exploration and development costs of $80,400, consisting of $78,200 of
professional fees paid to geological and exploration experts, and $2,200 paid
for sample analysis fees.

General and Administrative Expenses

         For the eleven-month period ended December 31, 2003, the Company
incurred general and administrative costs of $1,871,400. These expenses
consisted primarily of (1) salary, benefits and related expenses of $753,100,
including $46,100 of accrued salary expenses payable to the Chairman; (2)
executive, financial, and accounting consulting expenses of $706,500; (3) legal
and other professional fees of $99,600; (4) insurance expenses of 59,600; and
(5) travel and travel related expenses of $48,300.

Interest, Amortization, Depreciation and Other Income/(Expense)

         Other significant expenses of the Company consisted primarily of (1)
interest expenses of $372,100 related to the issuance of notes payable; (2)
$366,600 of amortization expense related to financing fees paid in conjunction
with the issuance of convertible notes in March 2003; and (3) $240,400 of
depreciation expense. These expenses were offset by $75,400 of other income
primarily derived from a $73,800 gain recognized with the sale of marketable
securities.

Common Stock Issuances for National Coal Corporation Prior to Reorganization

Issuance of Stock for Services

         In January 2003, a total of 15,350,000 shares of common stock were
granted to the four founding officers/directors of the Company for services
rendered. The stock was valued at $153,500 ($0.01 per share) based on stock
transactions for cash with unrelated individuals (see below).

Issuance of Stock for Cash

         In January and February 2003, a total of 1,750,000 shares of common
stock were sold to individuals for $17,500 ($0.01 per share).

Convertible Debt and Warrants to Purchase Common Stock

         In March 2003, the Company issued two convertible notes payable for a
total of $3,194,902. The notes and related accrued interest are convertible into
common stock at $0.50 per share. The convertible note holders also received
warrants to purchase a total of 1,597,250 shares of common stock at $0.55 per
share. The warrants have an expiration of two years from the date of issuance.
As of December 31, 2003, none of the warrants had been exercised.

                                      -29-
<PAGE>




Reorganization

         On March 28, 2003, National Coal Corporation (Tennessee) entered into
an Agreement and Plan of Reorganization to acquire 34.2 million shares of
Southern Group International, Inc. common stock for all of National Coal
Corporation's (Tennessee) outstanding common stock and $50,000 to retire 500,000
shares of SGI common stock. The $50,000 payment was made in March 2003 and
recorded as an administrative expense. The shares were exchanged on April 30,
2003. Immediately after the transaction, the former National Coal Corporation
(Tennessee) shareholders owned approximately 94.8% of SGI's common stock.
Coincident with the transaction, SGI changed its' name to National Coal
Corporation.

         The reorganization was recorded as a recapitalization effected by a
reverse merger wherein NCC/SGI was treated as the acquiree for accounting
purposes, even though it was the legal acquirer. Since SGI was a non-operating
entity with limited business activity, goodwill was not recorded. An unaudited
pro forma summary of consolidated net liabilities on March 31, 2003 is set forth
below:
<TABLE>
<CAPTION>
<S>                                      <C>                       <C>               <C>

                                               NCC                  NCC/SGI           Consolidated
                                               ---                  -------           ------------

Cash and equivalents                     $1,220,798                $      227         $ 1,221,025
Other current assets                          5,000                        -                5,000
Other assets                              1,736,510                        -            1,736,510
Notes payable and current liabilities
                                         (3,585,766)                  (13,922)         (3,599,688)
                                         -----------               ----------         -------------
Net liabilities                          $ (623,458)                 $(13,695)       $   (637,153)
                                         ===========               ===========        =============
</TABLE>

         The following unaudited pro forma consolidated results of operations is
for the twelve months ended March 31, 2003 and 2002 (which includes NCC activity
solely for the period since its inception to March 31, 2003) and assumes the
business combination had occurred April 1, 2001:

                                          Year Ended March 31,
                                        2003                  2002
                                        ----                  ----

Revenues                             $   -0-                $  -0-
                                       =======                ======
Net income (loss)                    $(804,705)             $(26,039)
                                       ==========             =========
Net income (loss) per share*         $  (.02)               $ (.00)
                                       ==========             =========

(*) Based on 1,887,381 SGI shares outstanding prior to the reverse merger and
34,200,000 SGI shares issued as a result of the merger.

         In management's opinion, the unaudited pro forma results of operations
are not indicative of the actual results that would have occurred if the
acquisition had taken place at the beginning of the periods presented and are
not intended to be a projection of future results.

Related Party Transactions

         On February 26, 2003, NCC acquired mining equipment and certain other
intangible mining rights and information from Strata Coal, LLC ("Strata") for
$47,000 ($7,000 cash and a non-interest bearing promissory note) and assumption
of promissory notes payable to unrelated parties totaling $174,000. The Company
also assumed $14,875 of Strata accounts payable. Strata is owned by the Chairman
of the Board and the President/CEO of NCC. Since the Strata transaction involved
related parties, primarily for intangible consideration, the $205,875 purchase
price (exclusive of the mining equipment subsequently sold - see below), has
been expensed. Subsequent to March 31, 2003 the promissory notes (totaling
$214,000) have been paid, and on June 11, 2003, the mining equipment was sold to
Jenco Capital Corporation ("Jenco") for $30,000. The President of NCC is also a
stockholder of Jenco.

                                      -30-
<PAGE>




         In February 2003, the Company borrowed $150,000 from a trust owned by
the Chairman of the Board. This note accrues simple interest at an annual rate
of 8% and was to mature in February 2005. In August 2003, the Company and
Chairman agreed to extend the maturity date of such note for three additional
years. The new maturity date is now February 20, 2008. No additional
compensation was paid to the Chairman for such maturity extension. The note is
classified as a current liability in the balance sheet due to the related party
nature of the obligation.

         On March 31, 2003, the Company paid the Chairman of the Board and its
President/CEO $150,000 each for organization, development and promotion
activities to get the Company started.

         On July 1, 2003, the Company sold mineral royalty rights for coal mined
on the Patterson Mountain portion of its' New River Tract for $75,156 to Jenco
Capital Corporation ("Jenco"), an entity partially owned by the CEO/President of
the Company. As consideration for the $75,156 received, the Company is obligated
to pay Jenco $2.00 per mined ton on the property. During the six months ended
December 31, 2003, the Company paid Jenco $59,572 in accordance with this
transaction.

         On August 1, 2003, the Company sold its interest in mineral royalty
rights received by the Company from U.S. Coal, Inc. for coal mined on the Smokey
Mountain portion of the New River Tract. The royalty was sold for $250,000 to
Jenco. As consideration for the $250,000 received, Jenco began receiving the
royalty payments from U.S. Coal. The Company recorded the transaction as
deferred revenue and recognizes revenue each month based on U.S. Coal's
production. As of December 31, 2003, royalties totaling $146,597 have been
recognized, leaving $103,403, which is included in deferred revenue.

         These transactions were completed by the Company with Jenco, a related
party, because (i) the Company needed a prompt capital infusion to ramp up coal
production, (ii) Jenco had available cash for the transaction, (iii) the Company
could not have developed another independent source for the capital without
considerable time delay due to lack of a production history, and (iv) the
Company had no knowledge of any outside sources for such capital. The Company
believes that given the time delay to search for capital and the cost of lost
opportunity, the terms of these transactions were acceptable because it afforded
immediate liquidity for operating purposes.

         On June 30, 2003, the Board of Directors assigned a ten-year, $0.25 per
ton royalty interest on all the coal sold from the Company's New River Tract, to
both the Chairman of the Board and the CEO/President. In the event any mineral
properties are sold prior to the end of the ten-year period, the obligation is
to be settled by paying 12 1/2% of the sales price to each individual. Pursuant
to the sale of mineral property rights to Jenco (see two paragraphs above), the
Company has recorded a liability to pay both the Chairman of the Board and the
CEO/President 12 1/2% of the sales price, a total of $81,289. The obligations
were paid in February 2004 and concurrently the June 30, 2003 agreements were
canceled.

         In August 2003, the Company borrowed $250,000, in October 2003, the
Company borrowed $25,000, and in December 2003, the Company borrowed $30,000,
from Jenco. In December 2003, the Company borrowed $105,000 from the
CEO/President of the Company. The notes payable accrue simple interest at an
annual rate of 8% and are payable on demand.

         In October 2003, the Company loaned the Chief Financial Officer $15,000
at an annual interest rate of 3 1/2% and a maturity of 1 year. This loan was
made during the period of time that the CFO was performing his duties on an
interim basis and was not considered an officer of the Company. In February
2004, this loan, plus accrued interest, was paid in full.

         During 2003, the Company paid the law firm of Kite, Bowen & Associates,
PA $45,000 for professional services rendered. Mr. Kite is the managing partner
of Kite, Bowen & Associates, PA, and is a director of the Company.

                                      -31-

<PAGE>





Common Stock Transactions

         Subsequent to the April 2003 merger of NCC/SGI, 1,350,000 shares of SGI
common stock were issued for a total of $270,000.

         In June 2003, 421,450 shares of SGI common stock were re-purchased for
$21,073 and cancelled.

Contract with Financial Consultants

         On April 7, 2003, the Company entered into a personal service contract
with a financial consultant at $2,500 per month for twelve months.

         On July 24, 2003, the Company contracted with a consultant to prepare a
Private Placement Memorandum describing the Company for $10,000.

Information Technology Contracts

         On April 3, 2003, the Company entered into a contract to acquire
managerial and financial application software for $38,250.

         On April 14, 2003, the Company retained a consultant to design the
Company's website for approximately $25,600.

Agreements with Officers

         In April and July 2003, the Board of Directors entered into employment
agreements with the Chairman, the President/CEO, and the Secretary/Treasurer
each for a two-year period providing for bonuses not to exceed fifty percent of
the annual salaries, and in September 2003 entered into an employment agreement
with the Chief Financial Officer for a six-month period providing for a bonus
not to exceed fifty percent of the annual salary, all as set forth below:


                  Chairman of the Board     $240,000
                  President & CEO            240,000
                  Chief Financial Officer    144,000
                  Secretary/Treasurer         96,000

         In March 2004, the Chairman agreed to reduce his annual base salary to
$36,000. This agreement was entered into as a result of the Chairman taking a
much less active role in the day-to-day operations of the Company. Concurrent
with this reduction in annual base salary, the Chairman, who had been accruing
his salary since October 2003, agreed to receive all previously accrued salary
in stock, using a price per share of $0.55. This resulted in the issuance of
167,832 shares to the Chairman in March 2004.

         In February 2004, the Chief Financial Officer agreed to a permanent
position with the Company, and as consideration, the Company increased his
annual base salary from $144,000 to $168,000.

         On June 30, 2003, the Board of Directors assigned a ten-year, $0.25 per
ton royalty interest on all the coal sold from the Company's New River Tract, to
both the Chairman of the Board and the CEO/President. In the event any mineral
properties are sold prior to the end of the ten-year period, the obligation is
to be settled by paying 12 1/2% of the sales price to each individual. Pursuant
to the sale of mineral property rights to Jenco (see two paragraphs above), the
Company has recorded a liability to pay both the Chairman of the Board and the
CEO/President 12 1/2% of the sales price, a total of $81,289. The obligations
were paid in February 2004 and concurrently the June 30, 2003 agreements were
canceled.

                                      -32-
<PAGE>




Commitments and Contingencies

Leases

         In March 2003, the Company agreed to lease space in Georgia, on a
month-to-month basis, at $600 per month. In April 2003, the Company entered into
an agreement to lease its' Knoxville office for nine months at $1,800 per month,
with an option to renew for an additional nine months. Rental expense for these
lease commitments totaled approximately $22,200 through December 31, 2003.

Acquisitions and Dispositions of Mineral Interests

         On April 9, 2003, the Company acquired approximately 65,000 acres of
coal mineral rights underlying properties in Anderson, Campbell and Scott
Counties, Tennessee for $1,270,000 (the "New River Tract"). A deposit for the
purchase price of the property was made on March 27, 2003, of which $40,000 was
paid to a law firm owned by a director of the Company.

         On May 20, 2003, the Company entered into a $1,196,000 contract to
acquire coal mineral rights underlying properties in Anderson and Campbell
Counties, Tennessee. The Company paid $50,000 in June as a deposit towards the
closing of this transaction, which was scheduled to close on July 8, 2003. The
closing did not occur on July 8, 2003, and the Company requested and
subsequently received an amendment to extend the closing date. The amended
agreement called for monthly payments, commencing September 22, 2003, of
$100,000, a portion of which would be paid as an interest charge. On September
30, 2003, the Company requested and subsequently received a second amendment,
which waived the $100,000 payment due on September 22, 2003. As consideration
for the extension, the Company paid $10,000. The Company subsequently missed the
next $100,000 payment date of October 22, 2003. Consequently, the Company no
longer has the right to acquire these properties, and in September 2003 the
Company wrote off the previously paid $60,000.

         On July 1, 2003, the Company sold mineral royalty rights for coal mined
on the Patterson Mountain portion of its' New River Tract for $75,156 to Jenco,
an entity partially owned by the CEO/President of the Company. As consideration
for the $75,156 received, the Company is obligated to pay Jenco $2.00 per mined
ton on the property. During the six months ended December 31, 2003, the Company
paid Jenco $59,572 in accordance with this transaction.

         On August 1, 2003, the Company sold its interest in mineral royalty
rights received by the Company from U.S. Coal, Inc. for coal mined on the Smokey
Mountain portion of the New River Tract. The royalty was sold for $250,000 to
Jenco. As consideration for the $250,000 received, Jenco began receiving the
royalty payments from U.S. Coal. The Company recorded the transaction as
deferred revenue and recognizes revenue each month based on U.S. Coal's
production. As of December 31, 2003, royalties totaling $146,597 have been
recognized, leaving $103,403, which is included in deferred revenue.

Mining Equipment

         In April and June 2003, the Company entered into contracts to purchase
mining equipment totaling $170,500. On May 30, 2003, the Company entered into
short-term lease agreements for mining equipment with initial combined monthly
rents totaling $91,900 and approximately $1,036,000 over the lease terms.

                                      -33-
<PAGE>

<TABLE>
<CAPTION>
<S>                                                                              <C>


Notes Payable

         Notes payable at December 31, 2003 consisted of the following:

1.   Convertible notes payable dated March 24, 2003, 12% interest,  payable with
     accrued  interest  upon the earlier of 1) March 25, 2004, or 2) the closing
     of certain financing, merger or disposition activities.  (Extended to March
     25, 2005)                                                                   $ 3,194,902

2.   Note payable to a trust owned by an officer  dated  February  20, 2003,  8%
     interest, payable with accrued interest upon the earlier of 1) February 20,
     2008,  or 2) the  closing  of  certain  financing,  merger  or  disposition
     activities.                                                                     150,000

3.   Note payable to an entity  partially  owned by an officer  dated August 27,
     2003,  8% interest,  payable with accrued  interest  upon the earlier of 1)
     February 27, 2004, or 2)  the closing of certain  financing,  merger
     or disposition activities.                                                      250,000

4.   Note payable to an entity  partially  owned by an officer dated October 30,
     2003, 8%  interest, and payable, with accrued interest, upon demand.             25,000

5. Note payable dated November 7, 2003, 10% interest, payable March 7, 2004.          33,000

6. Note payable dated November 7, 2003, 10% interest, payable March 7, 2004.          55,000

7.   Note payable dated  September 25, 2003, 12% interest,  payable with accrued
     interest  upon the earlier of 1) September  25, 2004,  or 2) the closing of
     certain financing, merger or  disposition activities.                            75,000

8.   Note payable dated  September 30, 2003, 12% interest,  payable with accrued
     interest  upon the earlier of 1) September  30, 2004,  or 2) the closing of
     certain financing, merger or disposition activities.                            195,315

9. Note payable dated November 7, 2003, 10% interest, payable March 7, 2004.          50,000

10. Note payable dated November 7, 2003, 10% interest, payable March 7, 2004.         60,000

11.  Note payable to an entity  partially  owned by an officer dated December 1,
     2003, 8%  interest, and payable, with accrued interest, upon demand.             30,000

12. Note payable to the President/CEO dated December 23, 2003, 8% interest, and
   payable, with accrued interest, upon demand.
                                                                                      95,000
13. Note payable to the President/CEO dated December 24, 2003, 8% interest, and
   payable, with accrued interest, upon demand.                                       10,000
                                                                                 --------------------
                                          Total                                   $4,223,217
                                                                                 ====================
</TABLE>


Other Contractual Obligations

         During the second calendar quarter, the Company entered into short-term
capital lease agreements to acquire four mining vehicles with a combined
estimated fair value of $775,916, which approximates the present value of the
minimum lease payments. Amortization is included in depreciation expense.

         Additionally, the Company rents other mining equipment pursuant to
operating lease agreements, and made lease payments totaling $307,478 during
2003.

         In March 2003, the Company agreed to lease space in Georgia, on a
month-to-month basis, at $600 per month. In April 2003, the Company entered into
an agreement to lease its' Knoxville office for nine months at $1,800 per month,
with an option to renew for an additional nine months. Rental expense for these
lease commitments totaled approximately $22,200 through December 31, 2003.

                                      -34-

<PAGE>





         A summary of future minimum payments under non-cancelable capital and
operating lease agreements, as well as other contractual obligations of the
Company, as of December 31, 2003 follows:
<TABLE>
<CAPTION>
<S>                                               <C>              <C>           <C>               <C>          <C>

        Other Contractual Obligations                                Payments due by period
        -----------------------------                                ----------------------
                                                              Less than 1                              More than 5
                                                  Total           year        1-3 years    3-5 years      years
                                                  -----           ----        ---------    ---------      -----

Capital Lease Obligations                           $476,000       $476,000           $0           $0           $0
Operating Leases                                    $138,000       $138,000           $0           $0           $0
Property Leases                                      $16,000        $16,000           $0           $0           $0
Employment Obligations                              $429,000       $336,000      $ 93,000          $0           $0
      Total Other Contractual Obligations         $1,059,000       $966,000      $ 93,000          $0           $0
</TABLE>


Liquidity

         As of December 31, 2003, the Company's had a cash and cash equivalents
position of $883.

         The Company's operations generated negative cash flow during the eleven
months ended December 31, 2003, and it expects a significant use of cash during
the first half of fiscal 2004 as the Company continues to initiate the business
opportunity for its' coal mining operations. It is anticipated that the current
cash reserves (including the cash raised in the February 2004 equity private
placement), plus expected generation of cash from operations, which have
recently commenced, will only be sufficient to fund the anticipated expenditures
into the third quarter of 2004. Consequently, the Company will require
additional equity or debt financing during the first half of 2004, the amount
and timing of which will depend in large part on the Company's spending program.
If additional funds are raised through the issuance of equity securities, the
current stockholders may experience dilution. Furthermore, there can be no
assurance that additional financing will be available when needed or that if
available, such financing will include terms favorable to the stockholders of
the Company. If such financing is not available when required or is not
available on acceptable terms, the Company may be unable to develop or enhance
its mining operations, take advantage of business opportunities or respond to
competitive pressures, any of which could have a material adverse effect on the
business, financial condition and results of operations of the Company.

         No operations were conducted and no operating revenue was realized from
January 30, 2003 to June 30, 2003, and the Company only began mining operations
during the calendar third quarter 2003. As of December 31, 2003, the Company was
totally illiquid and needed cash infusions from shareholders to provide capital,
or needed loans from any sources available. At December 31, 2003, the Company
had negative working capital of approximately $5,512,000 and a stockholders'
deficiency of approximately $2,927,000. These factors raise substantial doubt
about the Company's ability to continue as a going concern.

Short Term

         On a short-term basis, the Company does not generate revenue sufficient
to cover operations. Based on prior experience, the Company believes it will
continue to have insufficient revenue to satisfy current and recurring
liabilities as it seeks to develop its coal operations. For short-term needs,
the Company will be dependent on receipt, if any, of outside financing proceeds,
including debt and equity, any of which may be dilutive to existing
shareholders.

         At December 31, 2003, the Company's current assets of $181,270 were
exceeded by its current liabilities $5,693,115.

                                      -35-
<PAGE>




Long Term

         The Company has no cash commitments in hand from any source to fund its
long-term prospects. The Company does have a plan in place to resolve this
issue; it plans to raise outside capital from either debt or equity sources (or
both), however additional capital may or may not be available to the Company,
and if available, the terms may not be favorable to the Company and its'
shareholders. Failure to obtain long-term capital funding could result in
failure of the Company.

Capital Resources

         The primary capital resources of the Company are its common stock, and
coal as it is produced and sold.

Cash Flows

         The Company has only achieved negative cash flows to date, in the
amount of ($1,541,409) from operating activities. $3,533,171 was provided from
financing activities. The net loss for the eleven-month period ended December
31, 2003 was ($3,332,885). The Company expects cash flows to remain negative
from operations until production can be ramped up and/or new mines can be
opened, all of which requires additional capital for which the Company has no
committed sources, and there are no assurances that such funding sources can be
found.

Need for Additional Financing

         The Company does not have capital sufficient to meet the Company's cash
needs, or to expand its' mining business. The Company will have to seek loans or
equity placements to cover all cash needs. As operations increase, the Company's
need for additional financing is likely to increase, which will have a dilutive
effect to shareholders.

         No commitments to provide additional funds have been made by management
or other outside sources. Accordingly, there can be no assurance that any
additional funds will be available to the Company to allow it to cover its'
expenses and current liabilities as they incur. The Company is currently in
early stage discussions with multiple outside sources of capital, however no
assurances can be made about the successful outcome of these discussions.

                                      -36-
<PAGE>


                   DESCRIPTION OF PROPERTIES/ASSETS/TECHNOLOGY


(a) Real Estate.  Mineral Rights.


         The Company owns the following: 65,000 acres of coal mineral rights in
the "New River Tract." These mineral rights revert back to the surface owner on
June 5, 2093.


SEAM                   LOCATION                   MEASURED ACRES
====================== ========================== ====================
Jellico                Coon Pool Branch                           496
Jellico                Cage Creek                               1,230
Windrock               Buffalo Mountain                         1,632
Big Mary               High Point                                 567
Big Mary               High Point Mountain                        395
Big Mary               Ash Log Mountain                           593
Big Mary               Red Oak Mountain                           421
Walnut Mt.             High Point                                 193
Walnut Mt.             Buffalo Mountain                           624
Pewee                  Fork Mountain                              286
Pewee                  Stallion Mountain                          486
Pewee R                High Point                                 139
Pewee R                Burge Mountain                             380
Pewee R                Hannah Top                                  94


(b) Technology.  None.

(c) Patents.  None.


                RISK FACTORS RELATING TO THE COMPANY AND BUSINESS

         Several of the matters discussed in this document contain
forward-looking statements that involve risks and uncertainties. Factors
associated with the forward-looking statements that could cause actual results
to differ materially from those projected or forecast are included in the
statements below. In addition to other information contained in this report,
readers should carefully consider the following cautionary statements.

         Going Concern. The Company currently has a number of obligations that
it is unable to meet without generating additional revenues or raising
additional capital. If the Company cannot generate additional revenues or raise
additional capital in the near future, it may become insolvent. As of December
31, 2003, the Company's cash balance was a $883 and its' outstanding accounts
payable and accrued expenses totaled more than $832,000. Historically, the
Company has funded its capital requirements with debt and equity financing. Its
ability to obtain additional equity or debt financing depends on a number of
factors including the financial performance and the overall conditions in the
coal industry. If the Company is not able to raise additional financing or if
such financing is not available on acceptable terms, the Company may liquidate
assets, seek or be forced into bankruptcy, and/or continue operations, but
suffer material harm to its' operations and financial condition. These measures
could have a material, adverse affect on the Company's ability to continue as a
going concern.


                                      -37-
<PAGE>





         Competition. There are numerous competitors in the coal business with
substantially greater resources than the Company. Such resources could overwhelm
the Company's efforts to operate successfully and cause failure of the Company.

     Working Capital.  The working capital needs of the Company consist of: debt
reductions and interest  service,  mine  development,  property  acquisition and
exploration  costs,  bonding  costs,  equipment  expenditures  and  compensation
payments for mining.

         Limited Revenues. The Company has achieved limited revenues to date
consisting of approximately $1,800,000 in coal sales, through the end of
February 2004. There is no assurance that the Company can achieve any greater
sales or maintain any profitable sales.

         Industry Factors. The Company expects that many coal producers could
produce and sell coal at cheaper prices per ton than the Company's production
cost rates, which could adversely affect the Company's revenues and profits, if
any.

         Conflicts of Interest. Certain conflicts of interest may exist between
the Company and its officers and directors. They have other business interests
to which they devote their attention, and they may be expected to continue to do
so although management time should be devoted to the business of the Company. As
a result, conflicts of interest may arise that can be resolved only through
exercise of such judgment as is consistent with fiduciary duties to the Company.

         Need for Additional Financing. The Company has limited funds, and such
funds may not be adequate to carry out the business plan. The ultimate success
of the Company may depend upon its ability to raise substantial amounts of
additional capital. The Company has not investigated the availability, source,
or terms that might govern the acquisition of additional capital and will not do
so until it determines a need for additional financing. If additional capital is
needed, there is no assurance that funds will be available from any source or,
if available, that they can be obtained on terms acceptable to the Company. If
not available, the Company's operations will be limited to those that can be
financed with its modest capital and cash flows, if any.

         Regulation of Penny Stocks. The Company's securities, as traded on the
"Pink Sheets", will be subject to a Securities and Exchange Commission rule that
imposes special sales practice requirements upon broker-dealers who sell such
securities to persons other than established customers or accredited investors.
For purposes of the rule, the phrase "accredited investors" means, in general
terms, institutions with assets in excess of $5,000,000, or individuals having a
net worth in excess of $1,000,000 or having an annual income that exceeds
$200,000 (or that, when combined with a spouse's income, exceeds $300,000). For
transactions covered by the rule, the broker-dealer must make a special
suitability determination for the purchaser and receive the purchaser's written
agreement to the transaction prior to the sale. Consequently, the rule may
affect the ability of broker-dealers to sell the Company's securities and also
may affect the ability of purchasers in this offering to sell their securities
in any market that might develop therefore.

         In addition, the Securities and Exchange Commission has adopted a
number of rules to regulate "penny stocks". Such rules include Rules 3a51-1,
15g-1, 15g-2, 15g-3, 15g-4, 15g-5, 15g-6, 15g-7, and 15g-9 under the Securities
and Exchange Act of 1934, as amended. Because the securities of the Company may
constitute "penny stocks" within the meaning of the rules, the rules would apply
to the Company and to its securities. The rules may further affect the ability
of owners of the Company's common stock to sell the securities of the Company in
any market that might develop for them.

                                      -38-
<PAGE>




         Shareholders should be aware that, according to Securities and Exchange
Commission, the market for penny stocks has suffered in recent years from
patterns of fraud and abuse. Such patterns include (i) control of the market for
the security by one or a few broker-dealers that are often related to the
promoter or issuer; (ii) manipulation of prices through prearranged matching of
purchases and sales and false and misleading press releases; (iii) "boiler room"
practices involving high-pressure sales tactics and unrealistic price
projections by inexperienced sales persons; (iv) excessive and undisclosed
bid-ask differentials and markups by selling broker-dealers; and (v) the
wholesale dumping of the same securities by promoters and broker-dealers after
prices have been manipulated to a desired consequent investor losses. The
Company's management is aware of the abuses that have occurred historically in
the penny stock market. Although the Company does not expect to be in a position
to dictate the behavior of the market or of broker-dealers who participate in
the market, management will strive within the confines of practical limitations
to prevent the described patterns from being established with respect to the
Company's securities.

         Lack of Revenue History. The Company was formed to create a regional
coal producer in Tennessee. The Company had no revenues from inception until the
third quarter 2003 when it began mining operations. The Company is not
profitable and the business status is considered to be in an early development
stage. The Company must be regarded as a risky venture with all of the
unforeseen costs, expenses, problems, risks and difficulties to which such
ventures are subject.

         No Assurance of Success or Profitability. There is no assurance that
the Company will ever operate profitably. There is no assurance that it will
generate continued revenues or any profits, or that the market price of the
Company's common stock will be increased thereby.

         Lack of Diversification. Because of the limited financial resources
that the Company has, it is unlikely that the Company will be able to diversify
its operations. The Company's probable inability to diversify its activities
into more that one business area will subject the Company to economic
fluctuations within a particular business or industry and therefore increase the
risks associated with the Company's operations.

         Dependence upon Management. The Company currently has two individuals
who are serving as its officers on a full time basis and one executive who
serves as Chairman of the Board. One director serves on a part-time basis, about
20 hours a month. The Company is heavily dependent upon their skills, talents,
and abilities, as well as consultants to the Company, to implement its business
plan, and may, from time to time, find that the inability of the directors and
other officers to devote their full time attention to the business of the
Company results in a delay in progress toward implementing its business plan.

         Indemnification of Officers and Directors. Florida Revised Statutes
provide for the indemnification of its directors, officers, employees, and
agents, under certain circumstances, against attorney's fees and other expenses
incurred by them in any litigation to which they become a party arising from
their association with or activities on behalf of the Company. The Company will
also bear the expenses of such litigation for any of its directors, officers,
employees, or agents, upon such person's promise to repay the Company therefore,
if it is ultimately determined that any such person shall not have been entitled
to indemnification. This indemnification policy could result in substantial
expenditures by the Company that it will be unable to recoup.

         Director's Liability Limited. Florida Revised Statutes exclude personal
liability of its directors to the Company and its stockholders for monetary
damages for breach of fiduciary duty except in certain specified circumstances.
Accordingly, the Company will have a much more limited right of action against
its directors than otherwise would be the case. This provision does not affect
the liability of any director under federal or applicable state securities laws.

                                      -39-
<PAGE>




         Dependence upon Outside Advisors. To supplement the business experience
of its officers and directors, the Company may be required to employ
accountants, technical experts, appraisers, attorneys, or other consultants or
other advisors. The Company's CEO/President, without any input from
stockholders, will make the selection of any such advisors. Furthermore, it is
anticipated that such persons may be engaged on an "as needed" basis without a
continuing fiduciary or other obligation to the Company. In the event the
CEO/President of the Company considers it necessary to hire outside advisors, he
may elect to hire persons who are affiliates, if they are able to provide the
required services.

     No Foreseeable Dividends.  The Company has not paid dividends on its common
stock and does not anticipate paying such
dividends in the foreseeable future.

         Loss of Control by Present Management and Stockholders. The Company may
issue further shares as consideration for the cash or assets or services out of
the Company's authorized but not issued common stock that would, upon issuance,
represent a majority of the voting power and equity of the Company. The result
of such an issuance would be that those new stockholders and management would
control the Company, and persons unknown could replace the Company's management
at this time. Such an occurrence would result in a greatly reduced percentage of
ownership of the Company by its current shareholders.

         Limited Public Market Exists. There is a limited public market for the
Company's common stock in the "Pink Sheets", and no assurance can be given that
a market will continue or that a shareholder ever will be able to liquidate his
investment without considerable delay, if at all. The price may be highly
volatile. Factors such as those discussed in the "Risk Factors" section may have
a significant impact upon the market price of the securities offered hereby. Due
to the low price of the securities, many brokerage firms may not be willing to
effect transactions in the securities. Even if a purchaser finds a broker
willing to effect a transaction in these securities, the combination of
brokerage commissions, state transfer taxes, if any, and any other selling costs
may exceed the selling price. Further, many lending institutions will not permit
the use of such securities as collateral for any loans.

         Rule 144 Sales. All of the outstanding shares of common stock held by
present officers, directors, and affiliate stockholders are "restricted
securities" within the meaning of Rule 144 under the Securities Act of 1933, as
amended. As restricted shares, these shares may be resold only pursuant to an
effective registration statement or under the requirements of Rule 144 or other
applicable exemptions from registration under the Act and as required under
applicable state securities laws. Rule 144 provides in essence that a person who
has held restricted securities for one year may, under certain conditions, sell
every three months, in brokerage transactions, a number of shares that does not
exceed the greater of 1.0% of a company's outstanding common stock or the
average weekly trading volume during the four calendar weeks prior to the sale.
There is no limit on the amount of restricted securities that may be sold by a
non-affiliate after the owner has held the restricted securities for a period of
two years. A sale under Rule 144 or under any other exemption from the Act, if
available, or pursuant to subsequent registration of shares of common stock of
present stockholders, may have a depressive effect upon the price of the common
stock in any market that may develop.

                              INDUSTRY RISK FACTORS

If we are unable to achieve supply contracts, our revenues and operating profits
could suffer if we were unable to find buyers willing to purchase our coal at
profitable prices.

If  transportation  for our  coal  becomes  unavailable  or  uneconomic  for our
customers, our ability to sell coal could suffer.

         Transportation costs represent a significant portion of the total cost
of delivered coal and, as a result, the cost of transportation is a critical
factor in a customer's purchasing decision. Increases in transportation costs
could make our coal a less competitive source of energy or could make some of
our operations less competitive than other sources of coal. Some coal supply
agreements permit the customer to terminate the contract if the cost of
transportation increases by an amount ranging from 10% to 20%, in any given
12-month period.

                                      -40-
<PAGE>




         Coal producers depend upon rail, barge, trucking, overland conveyor and
other systems to deliver coal to markets. While U.S. coal customers typically
arrange and pay for transportation of coal from the mine to the point of use,
disruption of these transportation services because of weather-related problems,
strikes, lock-outs or other events could temporarily impair our ability to
supply coal to our customers and thus could adversely affect our results of
operations.

Risks inherent to mining could increase the cost of operating our business.

         Our mining operations are subject to conditions beyond our control that
can delay coal deliveries or increase the cost of mining at particular mines for
varying lengths of time. These conditions include weather and natural disasters,
unexpected maintenance problems, key equipment failures, variations in coal seam
thickness, variations in the amount of rock and soil overlying the coal deposit,
variations in rock and other natural materials and variations in geologic
conditions.

The  government  extensively  regulates  our mining  operations,  which  imposes
significant  costs on us, and future  regulations  could increase those costs or
limit our ability to produce coal.

         Federal, state and local authorities regulate the coal mining industry
with respect to matters such as employee health and safety, permitting and
licensing requirements, air quality standards, water pollution, plant and
wildlife protection, reclamation and restoration of mining properties after
mining is completed, the discharge of materials into the environment, surface
subsidence from underground mining and the effects that mining has on
groundwater quality and availability. In addition, significant legislation
mandating specified benefits for retired coal miners affects our industry.
Numerous governmental permits and approvals are required for mining operations.
We are required to prepare and present to federal, state or local authorities
data pertaining to the effect or impact that any proposed exploration for or
production of coal may have upon the environment. The costs, liabilities and
requirements associated with these regulations may be costly and time-consuming
and may delay commencement or continuation of exploration or production
operations. The possibility exists that new legislation and/or regulations and
orders may be adopted that may materially adversely affect our mining
operations, our cost structure and/or our customers' ability to use coal. New
legislation or administrative regulations (or judicial interpretations of
existing laws and regulations), including proposals related to the protection of
the environment that would further regulate and tax the coal industry, may also
require us or our customers to change operations significantly or incur
increased costs. The majority of our coal supply agreements contain provisions
that allow a purchaser to terminate its contract, if legislation is passed that
either restricts the use or type of coal permissible at the purchaser's plant or
results in specified increases in the cost of coal or its use. These factors and
legislation, if enacted, could have a material adverse effect on our financial
condition and results of operations.

         In addition, the United States and over 160 other nations are
signatories to the 1992 Framework Convention on Climate Change, which is
intended to limit emissions of greenhouse gases, such as carbon dioxide. In
December 1997, in Kyoto, Japan, the signatories to the convention established a
binding set of emission targets for developed nations. Although the specific
emission targets vary from country to country, the United States would be
required to reduce emissions to 93% of 1990 levels over a five-year budget
period from 2008 through 2012. Although the United States has not ratified the
emission targets and no comprehensive regulations focusing on U.S. greenhouse
gas emissions are in place, these restrictions, whether through ratification of
the emission targets or other efforts to stabilize or reduce greenhouse gas
emissions, could adversely impact the price of and demand for coal. According to
the Energy Information Administration's Emissions of Greenhouse Gases in the
United States 2001, coal accounts for 32% of greenhouse gas emissions in the
United States, and efforts to control greenhouse gas emissions could result in
reduced use of coal if electricity generators switch to sources of fuel with
lower carbon dioxide emissions. Further developments in connection with
regulations or other limits on carbon dioxide emissions could have a material
adverse effect on our financial condition or results of operations.

                                      -41-
<PAGE>




Our future success depends upon our ability to continue acquiring and developing
coal reserves that are economically recoverable.

     Our  recoverable  reserves will decline as we produce coal. We have not yet
applied for the permits  required or developed the mines necessary to use all of
the coal deposits under our mineral rights.  Furthermore,  we may not be able to
mine all of our coal deposits as profitably as we do at our current  operations.
Our future  success  depends  upon our  conducting  successful  exploration  and
development   activities  and  acquiring  properties   containing   economically
recoverable  coal deposits.  Our current strategy  includes  increasing our coal
deposits base through acquisitions of other mineral rights, leases, or producing
properties  and  continuing to use our existing  properties.  Additionally,  the
federal  government  limits the amount of federal land that may be leased by any
company to 150,000 acres nationwide. As of December 31, 2003, we leased no acres
from the  federal  government.  The limit  could  restrict  our ability to lease
significant federal lands.

         Our planned development and exploration projects and acquisition
activities may not result in the acquisition of significant additional coal
deposits and we may not have continuing success developing additional mines. Our
mining operations are conducted on mineral rights owned by us. Because title to
most of our mineral rights are not thoroughly verified until a permit to mine
the property is obtained, our right to mine some of our leased coal deposits may
be materially adversely affected, if defects in title or boundaries exist. In
addition, in order to develop our coal deposits, we must receive various
governmental permits. We cannot predict whether we will continue to receive the
permits necessary for us to operate profitably in the future.

If the coal industry  experiences  overcapacity in the future, our profitability
could be impaired.

         During the mid-1970s and early 1980s, a growing coal market and
increased demand for coal attracted new investors to the coal industry, spurred
the development of new mines and resulted in added production capacity
throughout the industry, all of which led to increased competition and lower
coal prices. Similarly, an increase in future coal prices could encourage the
development of expanded capacity by new or existing coal producers. Any
overcapacity could reduce coal prices in the future.

Our  operations  could be  adversely  affected if we fail to  maintain  required
surety bonds.

         Federal and state laws require bonds or cash deposits to secure our
obligations to reclaim lands used for mining, to pay federal and state workers'
compensation, to secure coal lease obligations and to satisfy other
miscellaneous obligations. As of December 31, 2003, we had outstanding $257,500
in cash deposited with the Department of the Interior for post-mining
reclamation. Reclamation surety bonds are typically renewable on a yearly basis,
if they are not posted with cash. Our failure to maintain, or inability to
acquire, surety bonds that are required by state and federal law would have a
material adverse effect on us. That failure could result from a variety of
factors including the following:

o    lack of  availability,  higher expense or  unfavorable  market terms of new
     surety bonds;

o    restrictions  on the  availability  of  collateral  for  current and future
     third-party  surety bond  issuers  under the terms of our  indenture or new
     credit facility; and

o    the exercise by third-party surety bond issuers of their right to refuse to
     renew the surety.

Our ability to operate our Company effectively could be impaired if we lose key
personnel.

         We manage our business with key personnel, the loss of whom could have
a material adverse effect on us. In addition, as our business develops and
expands, we believe that our future success will depend greatly on our continued
ability to attract and retain highly skilled and qualified personnel. We cannot
make any assurances that key personnel will continue to be employed by us or
that we will be able to attract and retain qualified personnel in the future. We
have "key person" life insurance covering the President/CEO,
Secretary/Treasurer, Directors, and the Operations Manager. Failure to retain or
attract key personnel could have a material adverse effect on us.

                                      -42-

<PAGE>




Terrorist attacks and threats, escalation of military activity in response to
such attacks or acts of war may negatively affect our business, financial
condition and results of operations.

         Terrorist attacks and threats, escalation of military activity in
response to such attacks or acts of war may negatively affect our business,
financial condition and results of operations. Our business is affected by
general economic conditions, fluctuations in consumer confidence and spending,
and market liquidity, which can decline as a result of numerous factors outside
of our control, such as terrorist attacks and acts of war. Future terrorist
attacks against U.S. targets, rumors or threats of war, actual conflicts
involving the United States or its allies, or military or trade disruptions
affecting our customers may materially adversely affect our operations. As a
result, there could be delays or losses in transportation and deliveries of coal
to our customers, decreased sales of our coal and extension of time for payment
of accounts receivable from our customers. Strategic targets such as
energy-related assets may be at greater risk of future terrorist attacks than
other targets in the United States. In addition, disruption or significant
increases in energy prices could result in government-imposed price controls. It
is possible that any, or a combination, of these occurrences could have a
material adverse effect on our business, financial condition and results of
operations.

Our ability to collect payments from our customers could be impaired due to
credit issues.

         Our ability to receive payment for coal sold and delivered depends on
the continued creditworthiness of our customers. Our customer base may not be
highly creditworthy. If deterioration of the creditworthiness of customers or
trading counterparties occurs, our business could be adversely affected.

                                      -43-
<PAGE>



Item 7.   Financial Statements

The  response to this item is  submitted  as a separate  section of this
report beginning on page F-1.

                                      -44-
<PAGE>




Item 8.       Changes in and Disagreements with Accountants on Accounting and
              Financial Disclosure

         In connection with the audits of the two most recent fiscal years and
any interim period preceding resignation, no disagreements exist with any former
accountant on any matter of accounting principles or practices, financial
statement disclosure, or auditing scope of procedure, which disagreements if not
resolved to the satisfaction of the former accountant would have caused him to
make reference in connection with his report to the subject matter of the
disagreement(s).

         The principal accountants' reports on the financial statements for any
of the past two years contained no adverse opinion or a disclaimer of opinion,
nor was qualified as to uncertainty, audit scope, or accounting principles
except for the "going concern" qualification.

Item 8a.     Controls and Procedures

Disclosure Controls & Procedures

         Within the 90-day period prior to the filing date of this report, the
Company's CEO/President and Chief Financial Officer, with the participation of
management, carried out an evaluation of the effectiveness of its' disclosure
controls and procedures pursuant to Exchange Act Rule 13a-14. Based upon that
evaluation, the CEO/President and Chief Financial Officer each believes that, as
of the date of the evaluation, the Company's disclosure controls and procedures
are effective in making known to them material information which would be
required to be included in this report.

         Disclosure controls and procedures, no matter how well designed and
implemented, can provide only reasonable assurance of achieving an entity's
disclosure objectives. The likelihood of achieving such objectives is affected
by limitations inherent in disclosure controls and procedures. These include the
fact that human judgment in decision-making can be faulty and that breakdowns in
internal control can occur because of human failures, such as simple errors or
mistakes or intentional circumvention of the established process.

         There were no significant changes in the internal controls or in other
factors that could significantly affect the Company's internal controls, known
to its' CEO/President and Chief Financial Officer, subsequent to the date of the
evaluation.

                                      -45-

<PAGE>



                                    PART III

Item 9.       Directors, Executive Officers, Promoters and Control Persons;
              Compliance With Section 16(a) of the Exchange Act

         The following table lists the names and ages of the executive officers
and directors of the Company. The directors, with the exception of Mr. Chmiel
who was appointed in February 2004, were appointed in May 2003 and will continue
to serve until the next annual shareholders meeting or until their successors
are appointed and qualified. All officers serve at the discretion of the Board
of Directors.

         NAME                  AGE           POSITION WITH THE COMPANY
         ----                  ---           -------------------------

         Jon Nix               34            President/CEO & Director
         Robert Chmiel         43            CFO & Director
         Jeanne Bowen Nix      33            Secretary/Treasurer/General Counsel
         Farrald Belote, Jr.   67            Chairman of the Board
         Charles Kite          59            Director

         JON NIX; age 34; President, Chief Executive Officer and Director. Mr.
Nix is National Coal's founder and possesses over eight years experience in the
financial industry. He is the founder of Jenco Capital Corporation, a Tennessee
consulting and holding corporation. He is also a cofounder of Medicine
Arm-In-Arm, Inc., a nonprofit children's charity that provides medical services
to underprivileged children around the world. He holds a Bachelor of Arts degree
in Economics from the University of Tennessee, 1992. He has been a director and
President of National Coal Corp., a Tennessee corporation, since January 2003,
which is the operating subsidiary.

         ROBERT CHMIEL; age 43; Chief Financial Officer and Director. From
December 2000 to April 2003 Mr. Chmiel served as CFO/COO of Brilliant Digital
Entertainment, Inc. (AMEX: BDE), a publicly traded software firm where he
managed 5 separate debt and equity financings. Previously, he was the
President/COO (1999-2000) and co-founder of Phase2Media, Inc., a privately held
Internet advertising sales and marketing firm. In 1998, Mr. Chmiel was CFO for
BarnesandNoble.com (NASDAQ: BNBN) prior to the company's IPO. Mr. Chmiel was
employed at the Walt Disney Company, where he served as Vice President, Finance
& Operations (1995-1998) for the original team that launched Disney's online
operations, after having joined the company in 1992 as Director of Finance &
Operations for Disney Magazine Publishing. His other business experience
includes working for Oppenheimer as an associate in the corporate finance
department, and started his career as an internal auditor for the Dun &
Bradstreet Corporation. Mr. Chmiel earned his MBA from the Wharton School of
Business at the University of Pennsylvania in 1987 and his BA in Economics from
the College of the Holy Cross in 1982.

         JEANNE BOWEN NIX; age 33; Secretary/Treasurer/General Counsel. Ms.
Bowen Nix has held a license to practice law in the State of Tennessee since
1997. She is a junior partner in the East Tennessee law firm of Kite, Bowen &
Associates, P.A. and specializes in general corporate matters and real estate
services. She graduated cum laude from the University of Tennessee in May of
1993 with a Bachelor of Arts degree in Psychology, and received her Juris
Doctorate degree from Louisiana State University Law School in May of 1997. Ms.
Bowen Nix has been Secretary and Treasurer of National Coal Corp., a Tennessee
corporation, since January 2003, which is the operating subsidiary.

     FARRALD  BELOTE,  JR.; age 68;  Chairman of the Board.  Mr.  Belote has had
business  experience  dating back to 1958 in the energy sector.  He is presently
CEO of Litigation Research in Houston,  TX (1995-date).  He is also a co-founder
of Medicine  Arm-In-Arm,  Inc., a nonprofit  children's  charity  that  provides
medical  services to  underprivileged  children around the world.  IBM Sales and
Marketing, 1964-1984: with emphasis on the energy sector. BA, Mathematics, Texas
A&M,  1958.  He has been a director of National  Coal  Corporation,  a Tennessee
corporation, since January 2003, which is the operating subsidiary.

                                      -46-
<PAGE>




         CHARLES KITE; age 59; Director. Mr. Kite, an attorney since 1973, is
outside corporate counsel of National Coal Corp. He has a general practice in
Sevierville, Tennessee, and specializes in commercial business representation,
tax representation and litigation, estate planning, and probate matters. After
serving ten years as the Senior Trial Attorney in the Office of the Chief
Counsel for the Internal Revenue Service in Philadelphia, Pennsylvania and in
Nashville, Tennessee, he transferred to Knoxville, Tennessee to assist in
opening the Knoxville branch of the law offices of Heiskell, Donelson, Bearman,
Adams, Williams & Kirsch. The next five years, Mr. Kite was a senior partner
with the law firm of Brabson, Kite & Vance in Sevierville, Tennessee, and
thereafter for the following seven years was a sole practitioner in association
with various attorneys in the East Tennessee area. He is currently, and from
1997 has been, the managing partner in the law firm of Kite, Bowen & Associates,
PA. He is a graduate of the University of Tennessee (JD-1973) and of Carson
Newman College (BA-1967). He has been a director of National Coal Corporation
since February 2003.

         Under the Florida Business Corporation Act and the Company's Articles
of Incorporation, as amended, the Company's directors will have no personal
liability to the Company or its' stockholders for monetary damages incurred as
the result of the breach or alleged breach by a director of his "duty of care".
This provision does not apply to the directors' (i) acts or omissions that
involve intentional misconduct or a knowing and culpable violation of law, (ii)
acts or omissions that a director believes to be contrary to the best interests
of the corporation or its shareholders or that involve the absence of good faith
on the part of the director, (iii) approval of any transaction from which a
director derives an improper personal benefit, (iv) acts or omissions that show
a reckless disregard for the director's duty to the corporation or its'
shareholders in circumstances in which the director was aware, or should have
been aware, in the ordinary course of performing a director's duties, of a risk
of serious injury to the corporation or its' shareholders, (v) acts or omissions
that constituted an unexcused pattern of inattention that amounts to an
abdication of the director's duty to the corporation or its' shareholders, or
(vi) approval of an unlawful dividend, distribution, stock repurchase or
redemption. This provision would generally absolve directors of personal
liability for negligence in the performance of duties, including gross
negligence.

         Insofar as indemnification for liabilities arising under the Securities
Act may be permitted to directors, officers or persons controlling the Company
pursuant to the foregoing provisions, the Company has been informed that in the
opinion of the Securities and Exchange Commission, such indemnification is
against public policy as expressed in the Act and is therefore unenforceable.

         The Company does not have an Audit Committee. The members of the Board
sit as the Audit Committee. Robert Chmiel sits as the qualified financial expert
on the Board of Directors, and is the CFO of the Company.


No director, officer or beneficial owner of more than 10% of the Company's
common stock, its only equity securities, or any other person subject to Section
16 of the Exchange Act failed to file reports required by Section 16(a) of the
Securities
Exchange Act during the most recent fiscal year or prior fiscal years, however
reports on Form 4 were late in filing for Jon Nix and Farrald Belote.

There are family relationships among the members of the Board of Directors and
Management ad follows:

Charles Kite, Director, is the Father of Jeanne Bowen Nix.
Jeanne Bowen Nix, Secretary Treasurer, is the wife of Jon Nix, President



                                      -47-

<PAGE>
<TABLE>
<CAPTION>



Item 10.      Executive Compensation

                    SUMMARY COMPENSATION TABLE OF EXECUTIVES
<S>                   <C>   <C>       <C>            <C>        <C>            <C>           <C>                        <C>

                                                     Other                      Securities       Long
                                                     Annual     Restricted     Underlying        Term                   All
Name &                                               Comp-        Stock          Options/    Compensation               Other
Principal                   Salary    Bonus          ensation    Award(s)          SARS        Options                  Compensation
Position              Year   ($)       ($)             ($)         ($)              (#)         (#)($)

-----------------------------------------------------------------------------------------------------------------------------------
Jon Nix
President             2003  161,538   150,000          0             0               0            0                       40,644 (*)

-----------------------------------------------------------------------------------------------------------------------------------
Jeanne Bowen Nix
Secretary/Treasurer   2003   64,615       0            0             0               0            0                          0

-----------------------------------------------------------------------------------------------------------------------------------
Robert Chmiel,        2003   47,753       0            0             0               0            0                          0
CFO
-----------------------------------------------------------------------------------------------------------------------------------
</TABLE>

<TABLE>
<CAPTION>

                  Directors' Compensation for 2003 Fiscal Year
<S>                  <C>           <C>        <C>            <C>       <C>           <C>                  <C>

                                                                       Securities
                     Annual                   Consulting     Number     Underlying     Long Term              All
                     Retainer      Meeting    Fees/Other      of         Options/    Compensation/          Other
                        Fees        Fees        Fees         Shares        SARS       Options SARS        Compensation
Name                     ($)         ($)         ($)         (#)            (#)          ($)                  ($)

-----------------------------------------------------------------------------------------------------------------------------------
Jon Nix
Director                 0           0            0           0             0            0                    0

-----------------------------------------------------------------------------------------------------------------------------------
Farrald Belote
Director                 0           311,538      0           0             0            0                    40,644 (*)

-----------------------------------------------------------------------------------------------------------------------------------
Charles Kite
Director                 0           0            45,000 (**) 0             0            0                     0

-----------------------------------------------------------------------------------------------------------------------------------
Robert Chmiel (***)
Director                 0           0            0           0             0            0                     0

-----------------------------------------------------------------------------------------------------------------------------------
(*) - Pursuant to a Royalty Agreement which provides for a $0.25 per ton bonus
and upon sale of mineral interests, a fee in lieu of continuing royalty may be
paid to release the royalty. This royalty agreement was cancelled in 2004.
</TABLE>

(**) - Legal fees paid to Kite, Bowen & Assoc., PA for professional legal fees.

(***) - Appointed in 2004.

Code of Ethics:

         The Company has not adopted a Code of Ethics as of the date of this
report.

                                      -48-
<PAGE>





Item 11.      Security Ownership of Certain Beneficial Owners and Management

         The following table sets forth certain information known to the Company
with respect to the beneficial ownership of the Company's common stock as of
March 23, 2004 by (i) each person who is known by the Company to own
beneficially more than 5% of the Company's common stock, (ii) each of the
Company's directors and executive officers, and (iii) all officers and directors
of the Company as a group. Except as otherwise listed below, the address of each
person is c/o National Coal Corporation, 319 Ebenezer Road, Knoxville, TN 37923.

         Name and Address of             Amount and nature of
         Beneficial Owner                Beneficial Ownership (1)  Percentage of
                                                                       Class
         - ---------------------------------------------------------------------
         Jon Nix (1)(2)(7)                      15,450,000                 36.3%
         - ---------------------------------------------------------------------
         Jeanne Bowen Nix (1)(2)(3)(6)             600,000                  1.4%
         - ---------------------------------------------------------------------
         Charles Kite (3)(6)                       600,000                  1.4%
         - ---------------------------------------------------------------------
         Farrald Belote, Jr. (4)(5)(8)          15,574,832                 36.6%
         - ---------------------------------------------------------------------
         Robert Chmiel                             100,000                  0.2%
         - ---------------------------------------------------------------------
         All Officers and Directors
         as a Group                             32,324,832                 76.0%
         - ---------------------------------------------------------------------
         Total Shares Issued and                42,552,162
         Outstanding

1.   Includes (i) 600,000  shares owned by Jeanne Bowen Nix, (ii) 400,000 shares
     owned by Perdase Holdings, Inc., an entity controlled by Jon Nix, and (iii)
     700,000 shares owned by Jenco Capital  Corporation,  an entity of which Jon
     Nix is a beneficial owner.

2.   Jon Nix and Jeanne Bowen Nix are husband and wife.

3.   Jeanne Bowen Nix is Charles Kite's stepdaughter.

4.   Includes  5,000,000 shares pursuant to an option agreement  between Mr. Nix
     and Mr. & Mrs.  Belote such that Mr. Nix has the option to  purchase  these
     shares not before June 1, 2004 and not after March 31, 2005.

5.   These shares are jointly owned with Arlene Belote, Mr. Belote's wife.

6.   These shares are jointly  owned with  Christine  Kite,  Mr. Kite's wife and
     mother of Jeanne Bowen Nix.

7.   Does not include  5,000,000 shares subject to an option agreement  between
     Mr. Nix and Mr. & Mrs.  Belote such that Mr. Nix has the option to purchase
     these shares not before June 1, 2004 and not after March 31, 2005.

8.   Includes  167,832 shares issued to Mr. Belote as payment for accrued salary
     between October 2003 and March 2004.

All of the above individuals disclaim any beneficial ownership in shares owned
by family members.

                                      -49-
<PAGE>




Item 12.      Certain Relationships and Related Transactions

         On February 26, 2003, NCC acquired mining equipment and certain other
intangible mining rights and information from Strata Coal, LLC ("Strata") for
$47,000 ($7,000 cash and a non-interest bearing promissory note) and assumption
of promissory notes payable to unrelated parties totaling $174,000. The Company
also assumed $14,875 of Strata accounts payable. Strata is owned by the Chairman
of the Board and the President/CEO of NCC. Since the Strata transaction involved
related parties, primarily for intangible consideration, the $205,875 purchase
price (exclusive of the mining equipment subsequently sold - see below), has
been expensed. Subsequent to March 31, 2003 the promissory notes (totaling
$214,000) have been paid, and on June 11, 2003, the mining equipment was sold to
Jenco Capital Corporation ("Jenco") for $30,000. The CEO/President of NCC is
also a stockholder of Jenco.

         In February 2003, the Company borrowed $150,000 from a trust owned by
the Chairman of the Board. This note accrues simple interest at an annual rate
of 8% and was to mature in February 2005. In August 2003, the Company and the
Chairman agreed to extend the maturity date of such note for three additional
years. The new maturity date is now February 20, 2008. No additional
compensation was paid to the Chairman for such maturity extension. The note is
classified as a current liability in the balance sheet due to the related party
nature of the obligation.

         On March 31, 2003, the Company paid the Chairman of the Board and the
CEO/President $150,000 each for organization, development and promotion
activities to get the Company started.

         On July 1, 2003, the Company sold mineral royalty rights for coal mined
on the Patterson Mountain portion of the New River Tract for $75,156 to Jenco,
an entity partially owned by the CEO/President of the Company. As consideration
for the $75,156 received, the Company is obligated to pay Jenco $2.00 per mined
ton on the property. During the six months ended December 31, 2003, the Company
paid Jenco $59,572 in accordance with this transaction.

         On August 1, 2003, the Company sold its interest in mineral royalty
rights received by the Company from U.S. Coal, Inc. for coal mined on the Smokey
Mountain portion of the New River Tract. The royalty was sold for $250,000 to
Jenco. As consideration for the $250,000 received, Jenco began receiving the
royalty payments from U.S. Coal. The Company recorded the transaction as
deferred revenue and recognizes revenue each month based on U.S. Coal's
production. As of December 31, 2003, royalties totaling $146,597 have been
recognized, leaving $103,403, which is included in deferred revenue.

         These transactions were completed by the Company with Jenco Capital
Corporation, a related party, because (i) the Company needed a prompt capital
infusion to ramp up coal production, (ii) Jenco had available cash for the
transaction, (iii) the Company could not have developed another independent
source for the capital without considerable time delay due to lack of a
production history, and (iv) the Company had no knowledge of any outside sources
for such capital. The Company believes that given the time delay to search for
capital and the cost of lost opportunity, the terms of these transactions were
acceptable because it afforded immediate liquidity for operating purposes.

         On June 30, 2003, the Board of Directors assigned a ten-year, $0.25 per
ton royalty interest on all the coal sold from the New River Tract, to both the
Chairman of the Board and the CEO/President. In the event any mineral properties
are sold prior to end of the ten-year period, the obligation is to be settled by
paying 12 1/2% of the sales price to each individual. Pursuant to the sale of
mineral property rights to Jenco Capital Corporation (see two paragraphs above),
the Company has recorded a liability to pay both the Chairman of the Board and
the President 12 1/2% of the sales price, a total of $81,289. In February 2004,
the President/CEO and Chairman of the Board each agreed to permanently cancel
all future royalty payments, which were to be made to each of them by the
Company pursuant to the June 30, 2003 agreement.

                                      -50-

<PAGE>





         In August 2003, the Company borrowed $250,000, in October 2003, the
Company borrowed $25,000, and in December 2003, the Company borrowed $30,000,
from Jenco. In December 2003, the Company borrowed $105,000 from the
CEO/President of the Company. The notes payable accrue simple interest at an
annual rate of 8% and are payable on demand.

         In October 2003, the Company loaned the Chief Financial Officer $15,000
at an annual interest rate of 3 1/2% and a maturity of 1 year. This loan was
made during the period of time that the CFO was performing his duties on an
interim basis and was not considered an officer of the Company. In February
2004, this loan, plus accrued interest, was paid in full.

         During 2003, the Company paid the law firm of Kite, Bowen & Associates,
PA a total of $45,000 for professional services rendered. Mr. Kite is the owner
of Kite, Bowen & Associates, PA, and is a director of the Company.

         In January 2004, the Company borrowed $10,000 from Jenco. The note
payable accrues simple interest at an annual rate of 8% and is payable on
demand.

         In February 2004, the Company repaid (i) $105,000 in principal and
$1,024 in accrued interest to the CEO/President of the Company, and (ii) $65,000
in principal and $998 in accrued interest to Jenco.

         In February 2004, four unrelated parties, holding an aggregate
principal amount of $198,000 of notes payable, accepted an offer from the
Company to convert all of their then outstanding principal and accrued interest
into common shares of the Company at a conversion price of $0.55 per share.
Consequently, the Company issued 368,399 shares collectively of its common
stock, with 360,000 representing the conversion of principal due, and 8,399
representing accrued interest.

         In February 2004, Crestview Capital Master, LLC ("Crestview"), an
entity controlled by Crestview Capital Funds, directly purchased four
outstanding notes payable debt of the Company, from an unrelated party, in the
aggregate principal amount of $3,465,200, plus unpaid interest. Concurrent with
the repurchase of this debt, Crestview agreed to extend the maturity date on all
four notes to March 25, 2005 and to modify certain provisions. The interest rate
remains at 12% per annum. Two of the original notes, in the aggregate principal
amount of approximately $3.2 million, each of which had a conversion option into
common shares of the Company at a conversion price of $0.50 per share, have been
modified to preclude conversion if the issuance would cause Crestview to own
more that 9.99% of the then outstanding equity in the Company when computed in
accordance with Section 13d of the Securities and Exchange Act of 1934.
Crestview also purchased warrants from the debt holder, which had been
concurrently issued with the original two notes. Those warrants allow for
Crestview to purchase 1,597,250 shares of common stock at a price per share
equal to $0.55 until March 25, 2005.

         In March 2004, the Chairman agreed to reduce his annual base salary to
$36,000. This agreement was entered into as a result of the Chairman taking a
much less active role in the day-to-day operations of the Company. Concurrent
with this reduction in annual base salary, the Chairman, who had been accruing
his salary since October 2003, agreed to receive all previously accrued salary
in stock, using a price per share of $0.55. This resulted in the issuance of
167,832 shares to the Chairman in March 2004.

                                      -51-
<PAGE>




Item 13.      Exhibits, List and Reports on Form 8-K

(a)      Exhibits:

         The following exhibits are filed as part of this report:

         31.1 Certification pursuant to Section 302 of the Sarbanes Oxley Act of
         2003 (Jon Nix) 31.2 Certification pursuant to Section 302 of the
         Sarbanes Oxley Act of 2003 (Robert Chmiel) 32.1 Certification of
         Disclosure pursuant to Section 906 of the Sarbanes Oxley Act of 2002
         (b) Reports on Form 8-K.

         Index of Exhibits


3.1      Articles of Incorporation (*)

3.2      Bylaws (*)

3.3      Articles of Amendment (*)

10.1     Share Purchase Agreement (*)

10.2     Plan & Agreement of Reorganization (*)

10.3     Webb Group Note (*)

10.4      Modified Note for $1,691,885 (*)

10.5      Note for 75,000 (*)

10.6      Note for 195,314 (*)

10.7      Warrant to Webb Group for 751,500 shares*

10.8      Warrant to Webb Group for 845,750 shares*

10.9      Warrant Modification for 845,750 shares*

10.10     Warrant Modification for 751,500 shares*


         (*) - Incorporated by reference to filings made pursuant to Section 13
of the Securities & Exchange Act of 1934.

(b)      Reports on Form 8-K.

         8K 12G3  December 18, 2003

         8K                August 7, 2003

         8K                April 24, 2003

Item 14.      Principle Accounting Fees and Services

         General. Gordon, Hughes & Banks, LLP is the Company's principal
independent auditing accounting firm (the "Auditors"). The Company's Board of
Directors has considered whether the provisions of the audit services are
compatible with maintaining the independence of its Auditors. Gordon, Hughes &
Banks provides only auditing and tax preparation functions and no other services
to the Company.

                                      -52-
<PAGE>




         Audit Fees. Gordon, Hughes & Banks, LLP billed the Company $34,300 for
the following professional services: audit of the annual financial statement of
the Company for the fiscal year ended December 31, 2003, and reviews of the
interim financial statements included in quarterly reports on Form 10-QSB for
the periods ended June 30, 2003, and September 30, 2003. Gordon, Hughes & Banks
billed the Company $18,800 for the audit dated March 31, 2003.

         There were no tax fees paid to Gordon, Hughes & Banks in 2002 or 2003,
however in 2003, the Company did pay $2,600 related to the review of a private
placement memorandum used by the Company to raise capital.

         The Company's Board acts as the Audit Committee and had no
"pre-approval policies and procedures" in effect for the auditors' engagement
for the audit years 2002 and 2003. No fees other than Audit Fees were incurred
or approved by the Board.

         All audit work was performed by the full time employees of the
Auditors.

                                      -53-

<PAGE>



                                   SIGNATURES

         Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, as amended, the Registrant caused this report to be signed
on its behalf by the undersigned, thereunto duly authorized.

                                                    NATIONAL COAL CORPORATION


Date: March 26, 2004
                                                    ----------------------------
                                                    By:    Robert Chmiel
                                                    Its: Chief Financial Officer
                                                        (Principal Financial and
                                                         Accounting Officer)


                                                    Directors:

                                                    ----------------------------
                                                    Jon Nix

                                                    ----------------------------
                                                    Farrald Belote

                                                    ----------------------------
                                                    Charles Kite

                                                    ----------------------------
                                                    Robert Chmiel

                                      -54-
<PAGE>

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS


                                                                            Page


I.   Report of Independent Public Accountants                               F-1

II.  Financial Statements:

         Consolidated Balance Sheet at December 31, 2003                    F-2

         Consolidated Statement of Operations for the
         Eleven Months Ended December 31, 2003                              F-3

         Consolidated Statement of Cash Flows for the
         Eleven Months Ended December 31, 2003                              F-4

         Condensed Consolidated Statement of Changes in Stockholders'
         Deficiency
         Inception (January 30, 2003) to December 31, 2003                  F-5

         Notes to the Consolidated Financial Statements             F-6 to F-19


<PAGE>




REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS




To the Board of Directors
National Coal Corporation
Knoxville, Tennessee


We have audited the consolidated balance sheet of NATIONAL COAL CORPORATION as
of December 31, 2003, and the related consolidated statements of operations,
cash flows and changes in stockholders' deficiency for the period from its
inception (January 30, 2003) to December 31, 2003. 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 in accordance with auditing standards generally accepted
in the United States of America. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audit provides a
reasonable basis for our opinion.

In our opinion, the accompanying consolidated financial statements referred to
above present fairly, in all material respects, the financial position of
NATIONAL COAL CORPORATION at December 31, 2003, and the results of its
operations and its cash flows for the period from its inception to December 31,
2003, in conformity with accounting principles generally accepted in the United
States of America.

The accompanying financial statements have been prepared assuming that the
Company will continue as a going concern. As discussed in Note 1 to the
financial statements, the Company's significant operating losses, working
capital deficit and stockholders' deficiency raise substantial doubt about its
ability to continue as a going concern. The financial statements do not include
any adjustments that might result from the outcome of this uncertainty.


/s/Gordon, Hughes & Banks


Greenwood Village, Colorado
February 13, 2004

                                      F-1

<PAGE>
<TABLE>
<CAPTION>



                            NATIONAL COAL CORPORATION
                           CONSOLIDATED BALANCE SHEET
                                December 31, 2003
<S>                                                                                                       <C>

ASSETS
Current Assets:
   Cash and cash equivalents                                                                                        $ 883
   Accounts receivable                                                                                              4,327
   Inventory                                                                                                      145,863
   Prepaid and other                                                                                               30,197
                                                                                                          ----------------
Total current assets                                                                                              181,270
                                                                                                          ----------------

Property and Equipment:
   Mining equipment                                                                                             1,057,566
   Computer equipment and software                                                                                 79,969
   Automobile and mobile equipment                                                                                 61,232
   Office equipment and furniture                                                                                  25,611
                                                                                                          ----------------
                                                                                                                1,224,378
   Less: accumulated depreciation                                                                               (240,440)
                                                                                                          ----------------
Property and Equipment, net                                                                                      983,938
                                                                                                          ----------------
                                                                                                                1,362,190
Coal and Mineral Rights, net of $3,040 accumulated depletion                                                    1,362,190
Reclamation Bond                                                                                                  257,500
Loan acquisition costs, less accumulated amortization of $366,628                                                  45,607
                                                                                                          ----------------
Total Assets                                                                                                  $ 2,830,505
                                                                                                          ================
LIABILITIES AND STOCKHOLDERS' DEFICIENCY
Current Liabilities:
   Notes payable                                                                                              $ 3,663,217
   Notes payable to related parties                                                                               560,000
   Capital lease obligations                                                                                      458,803
   Accrued royalty payable to officers                                                                             81,289
   Accounts payable and accrued expenses, other than payroll related expenses                                     469,005
   Accrued payroll, including payroll taxes                                                                       180,154
   Accrued interest payable                                                                                       101,597
   Deferred revenue                                                                                               179,050
                                                                                                          ----------------
Total current liabilities                                                                                       5,693,115
Accrued Reclamation Expenses                                                                                       64,359
                                                                                                          ----------------
Total Liabilities                                                                                               5,757,474
                                                                                                          ----------------
Stockholders' Deficiency:

  Preferred stock, $.0001 par value; 10 million shares authorized; none issued
        and outstanding                                                                                                -

  Common stock, $.0001 par value; 80 million shares authorized; 37,015,931
        issued and outstanding                                                                                      3,702
  Additional paid-in capital                                                                                      402,214
  Accumulated deficit                                                                                         (3,332,885)
                                                                                                          ----------------
Total Stockholders' Deficiency                                                                                (2,926,969)
                                                                                                          ----------------
Total Liabilities and Stockholders' Deficiency                                                                $ 2,830,505
                                                                                                          ================

                 See Notes to Consolidated Financial Statements.
</TABLE>
                                      F-2

<PAGE>




                            NATIONAL COAL CORPORATION
                      CONSOLIDATED STATEMENT OF OPERATIONS
                      Eleven Months Ended December 31, 2003

REVENUES
    Coal sales                                                      $ 1,012,520
    Royalties                                                           178,123
                                                                       ---------
       Total revenue                                                  1,190,643

EXPENSES
    Cost of mine operations and selling expenses                      1,657,570
    General and administrative                                        1,871,414
    Exploration and development                                          80,367
    Depreciation, depletion and accretion                               250,527
    Amortization                                                        366,628
                                                                       ---------

       Total operating expenses                                       4,226,506
                                                                       ---------

LOSS FROM OPERATIONS                                                 (3,035,863)
                                                                      ----------

OTHER INCOME (EXPENSE)
    Gain on sale of marketable securities                                73,825
    Other income                                                          1,612
    Interest expense                                                   (372,459)
                                                                      ----------
       Total other income (expense)                                    (297,022)

                                                                      ----------
NET (LOSS)                                                          $(3,332,885)
                                                                      ==========

BASIC AND DILUTED NET (LOSS) PER SHARE                                  $ (0.09)
                                                                      ==========

WEIGHTED AVERAGE COMMON SHARES                                       36,550,518
                                                                      ==========

                 See Notes to Consolidated Financial Statements.

                                      F-3
<PAGE>
<TABLE>
<CAPTION>



                            NATIONAL COAL CORPORATION
                       CONSOLIDATED STATEMENT OF CASH FLOW
                      Eleven Months Ended December 31, 2003
<S>                                                                                                       <C>

CASH FLOWS FROM OPERATING ACTIVITIES
  Net (loss)                                                                                              $ (3,332,885)
  Adjustments to reconcile net (loss) to net cash provided by operating
    activities
             Depreciation and depletion                                                                        243,480
             Amortization                                                                                      366,628
             Accretion of accrued reclamation expenses                                                           7,047
             Stock issued for services                                                                         153,500
             Non-cash compensation                                                                             191,000
             Changes in operating assets and liabilities:
                  Receivables                                                                                   (4,327)
                  Inventory                                                                                   (145,863)
                  Prepaid and other                                                                            (30,197)
                  Accounts payable and accrued liabilities                                                     831,158
                  Deferred revenue                                                                             179,050
                                                                                                           -----------
                              Net cash flows provided (to) operating activities                             (1,541,409)
                                                                                                           -----------

CASH FLOWS FROM INVESTING ACTIVITIES
  Reclamation bond                                                                                            (257,500)
  Acquisition of coal and mineral rights                                                                    (1,307,917)
  Equipment and vehicles purchased                                                                            (448,462)
  Sale of mining equipment to related party                                                                     23,000
                                                                                                           ------------
                       Net cash flows provided from (to) investing activities                               (1,990,879)
                                                                                                           ------------

CASH FLOWS FROM FINANCING ACTIVITIES
  Proceeds from issuance of convertible debt, less acquisition costs                                         2,782,667
  Proceeds from issuance of debt                                                                               467,689
  Proceeds from issuance of related party debt                                                                 560,000
  Payment of notes payable                                                                                    (226,500)
  Payments on capital leases                                                                                  (317,112)
  Proceeds from issuance of common stock                                                                       287,500
  Repurchase and cancellation of common stock                                                                  (21,073)
                                                                                                           ------------
                       Net cash flows provided from (to) financing activities                                3,533,171
                                                                                                           ------------

NET INCREASE IN CASH                                                                                               883

CASH AND EQUIVALENTS, BEGINNING OF PERIOD                                                                            -
                                                                                                           ------------

CASH AND EQUIVALENTS, END OF PERIOD                                                                             $  883
                                                                                                           ============

SUPPLEMENTAL DISCLOSURES
   Interest paid                                                                                             $ 270,862
   Income taxes paid                                                                                                 -
   Non-cash investing and financing transactions:
     Net liabilities of Southern Group International, Inc. at the date of
      reverse merger                                                                                            14,012
     Capital lease obligations to acquire mining equipment                                                     775,916
     Recognition of accrued reclamation expenses                                                                57,312
     Assumption of promissory notes from Strata Coal, LLC:
              Charged to operations                                                                            191,000
              Partial payment of mining equipment                                                               23,000

                 See Notes to Consolidated Financial Statements.

                                      F-5
</TABLE>


<PAGE>
<TABLE>
<CAPTION>



                            NATIONAL COAL CORPORATION
                      CONSOLIDATED STATEMENT OF CHANGES IN
                            STOCKHOLDERS' DEFICIENCY
<S>                           <C>             <C>         <C>            <C>            <C>        <C>           <C>

                                                 Common Stock                      Additional
                              --------------------------------------------------
                                        NCC                       SGI               Paid- In      Accumulated
                              --------------------------------------------------
                                 Shares       Amount      Shares        Amount       Capital        Deficit         Total
                                 ------       ------      ------        ------       -------        -------         -----


Inception, January 30, 2003               -         $-             -          $-              $-             $-            $-

 Issuance of stock for                                             -           -               -              -
 services                        15,350,000    153,500                                                                153,500

 Sale of stock for cash           1,750,000     17,500             -           -               -              -        17,500

 Reorganization April 2003:

    Net liabilities of SGI                -          -     1,887,381         189         177,034        (191,235)     (14,012)
    Issuance of SGI shares to
     NCC shareholders           (17,100,000)  (171,000)   34,200,000       3,420         (23,655)        191,235            -

 Sale of stock for cash                   -          -     1,350,000         135         269,865               -      270,000

 Repurchase and cancellation              -          -      (421,450)        (42)        (21,030)              -      (21,072)

 Net (loss)                               -          -             -           -               -      (3,332,885)  (3,332,885)
                              -------------   ---------   ----------     -------        --------   ------------  ------------

Balance, December 31, 2003               -        $ -     37,015,931     $3,702         $402,214   ($3,332,885)  ($2,926,969)
                              =============   =========   ==========     =======        ========   ============  ============



                                See Notes to Consolidated Financial Statements.

                                      F-6
</TABLE>



<PAGE>



1. Business and Basis of Presentation

         National Coal Corporation was incorporated in Tennessee on January 30,
2003. On March 28, 2003, National Coal Corporation entered into a Share Purchase
Agreement whereby it purchased from an unrelated individual, 500,000 shares, or
22%, of Southern Group International, Inc. ("SGI"), a company incorporated in
the State of Florida on August 10, 1995. These 500,000 shares were cancelled on
April 11, 2003, when the Board of Directors of SGI approved an Agreement and
Plan of Reorganization whereby all the outstanding shares of National Coal
Corporation were exchanged on April 30, 2003 for 34,200,000 shares of Southern
Group International, Inc. See Footnote #6.

         Articles of Amendment to the Articles of Incorporation were filed in
with the Secretary of State's Office in Florida on August 4, 2003 changing the
name of Southern Group International, Inc. to National Coal Corporation ("NCC",
"National Coal" or the "Company" hereafter). National Coal Corporation
(Tennessee) operates as a wholly owned subsidiary of National Coal Corporation,
a Florida corporation. The Company was inactive prior to the acquisition of
National Coal Corporation (Tennessee) in April 2003.

         The principal activity of the Company is coal mining. The Company
currently owns, in fee simple, the coal mineral rights to the New River Tract
assemblage, which consists of approximately sixty-five thousand (65,000) acres
that lie in Anderson, Campbell and Scott Counties, approximately twenty-five
miles northwest of Knoxville, Tennessee. These mineral rights revert back to the
surface owner on June 5, 2093. At the present time there are two separate areas
located on the New River Tract assemblage that are producing coal which include
(1) a surface mine situated in Devonia, Tennessee (Patterson Mountain), and (2)
a portion of the New River Tract mined by U.S. Coal, Inc., an independent mine
operator that pays royalties to the Company on its' coal production.

         The Company engages in coal production by locating, assembling,
leasing, assessing, permitting and developing coal properties in Eastern
Tennessee. The Company, after obtaining permits from the U.S. Department of the
Interior, mines said properties or contracts with independent mine operators for
extraction of the coal minerals on a negotiated fee basis. Some contracts may be
on a per ton basis, and some may be on a cost plus basis. The variance is
usually due to varying extraction conditions and circumstances. Reclamation
bonds are obtained and maintained by the Company for each producing property.
Bonds typically take the form of cash deposits with the U.S. Department of the
Interior, Office of Surface Mining. In theory, insurance bonds could be used,
but such are extremely difficult and time consuming for small companies to
obtain in the market.

         The Company currently sells its' production into the spot market and/or
based on short-term contracts, but in the future intends to seek long-term
supply contracts. No such long-term contracts have been negotiated to date.

         Many of the Company's properties have been subject to limited
production in the past. Some of the properties were abandoned by previous
producers due to poor market conditions, uneconomical production, high labor
costs and/or reclamation bond difficulties.

         The Company maintains an umbrella liability insurance policy for all of
its operations, and requires liability policies to be furnished by contract
operators, naming the Company as a co-insured.

         The coal industry has been highly competitive with very thin margins in
recent years. Only in the past two years, in the opinion of management, have the
economics begun to look favorable for coal again. This situation is due to,
among other things, the surge in prices of natural gas. The price increases of
natural gas, on a Btu basis, have reached the point that coal fired power
plants, using the latest clean air compliant scrubber technology, can be price
competitive with natural gas fired plants.

                                      F-7
<PAGE>





         The Company intends to exploit its mineral rights by opening mines, as
its capital will allow, but it can only open a mine with an estimated $500,000
to $750,000 per mine, including bonds or cash deposited. Due to the operating
capital constraints, if the Company cannot raise such needed additional amounts
by loans or private placements, it will prevent the Company from expanding its
mining operations beyond the current operations.

         Since the formation of National Coal Corporation on January 30, 2003,
it had been deemed to be in the exploration stage because the Company did not
have any direct coal mining operations or proven reserves. However, during the
three-month period ended September 30, 2003, production commenced and
accordingly, the Company is no longer considered to be in the exploration stage.

Going Concern Uncertainty

         The accompanying audited consolidated financial statements have been
prepared assuming that the Company will continue as a going concern, which
contemplates the realization of assets and the satisfaction of liabilities in
the normal course of business. The carrying amounts of assets and liabilities
presented in the financial statements do not purport to represent realizable or
settlement values. No operations were conducted and no operating revenue was
realized from January 30, 2003 to June 30, 2003, and the Company only began
mining operations thereafter. As of December 31, 2003, the Company was totally
illiquid and needed cash infusions from shareholders to provide capital, or
needed loans from any source available. At December 31, 2003, the Company had
negative working capital of approximately $5,512,000 and a stockholders'
deficiency of approximately $2,927,000. These factors raise substantial doubt
about the Company's ability to continue as a going concern.

         The Company is seeking additional funding and believes that this will
result in improved operating results. There can be no assurance, however, that
the Company will be able to secure additional funding, or that if such funding
is available, whether the terms or conditions would be acceptable to the
Company.

2.       Summary of Significant Accounting Policies

Principles of Consolidation

         The accompanying financial statements include the accounts of National
Coal Corporation (Tennessee) from its' inception and of SGI since the April 2003
merger. All intercompany transactions and balances from the date of the merger
have been eliminated in consolidation.

Use of Estimates

         The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that materially affect the amounts reported in the financial
statements and accompanying notes. Actual results could materially differ from
those estimates.

Revenue Recognition

         Under SEC Staff Accounting Bulletin No. 101, "Revenue Recognition in
Financial Statements," the Company recognizes revenue when all of the following
criteria are met: (1) persuasive evidence of an arrangement exists, (2) delivery
has occurred or services have been rendered, (3) the seller's price to the buyer
is fixed or determinable, and (4) collectibility is reasonably assured. In the
case of the Company's product, a price is negotiated with each customer with
specifics for requirements, a fixed price per ton, a delivery schedule, and
terms for payment. Unless cash is paid in advance, accounts receivables are
recorded as revenue is earned. The Company regularly evaluates the
collectibility of its' receivables based on a combination of factors. To date,
the Company has not had any customer whose payment was considered past due, and
as such has not had to record any reserves for doubtful collectibility.

                                      F-8

<PAGE>




         Coal Sales

         The Company currently sells its' coal in raw form (i.e. the coal has
not been processed, washed or cleaned in any manner), on a per ton basis. Sales
typically are through a third party broker and the Company pays a commission (on
a per ton basis) to the broker. Brokered sales are typically to state utility
companies. The Company also sells direct to other coal producers, as well as
direct to consumers.

         Each sale is made at a negotiated price. The price charged is typically
for a specified tonnage amount, referred herein as a "contract price." Sales are
also priced on a one-day or one-shipment tonnage amount. The price per ton for
these types of sales typically fluctuates in direct correlation to the price per
ton of coal quoted on the New York Mercantile Exchange, referred to as the "spot
price." All of the Company's sales are for short-term contracts (i.e. the amount
of tonnage committed to be sold can typically be delivered in less than two
weeks).

         The Company recognizes revenue from coal sales at the time title passes
to the customer, which generally takes place near the Company's mine site. The
Company does not provide or arrange for transportation of coal and therefore,
"pass through" shipping costs are not included in either coal sales or the cost
of mining operations and selling expenses.

         Royalties

         During the eleven-month period from inception (January 30, 2003) to
December 31, 2003, the Company recorded royalties for coal mined by U.S. Coal,
Inc. on a portion of the New River Tract. In August 2003, this royalty right was
sold for $250,000 to Jenco Capital Corporation, an entity partially owned by the
CEO/President of the Company (see Footnote #7). At December 31, 2003, $103,403
of the amount of the royalty sold to Jenco was recorded as deferred revenue,
pending future production by U.S. Coal, Inc. The Company expects to recognize
this remaining revenue deferral during the first six months of 2004.

Cost of Mining Operations and Selling Expenses

         Cost of mining operations and selling expenses consists primarily of
direct compensation and benefits cost for miners, as well as direct costs such
as equipment lease and maintenance, blasting, fuel, parts, hauling costs, and
commissions paid to third party brokers.

Exploration Costs

         Costs related to locating coal deposits and determining the economic
mineability of such deposits are expensed as incurred.

Compensation

         The Company accounts for stock-based compensation using Accounting
Principles Board's Opinion ("APB") No. 25, "Accounting for Stock Issued to
Employees". Under APB No. 25, compensation expense is recognized for stock
options with an exercise price that is less than the market price on the grant
date of the option. For stock options granted employees or directors with
exercise prices at or above the market value of the stock on the grant date, the
Company has adopted the Financial Accounting Standards Board ("FASB")
disclosure-only provisions of Statement of Financial Accounting Standards No.
123, "Accounting for Stock-Based Compensation" ("SFAS 123").

         As of December 31, 2003, the Company did not have any employee
stock-based compensation programs. However, in February 2004 a stock option plan
was presented to shareholders for approval. See Footnote #9.

                                      F-9
<PAGE>





Comprehensive Income

         There are no adjustments necessary to the net loss as presented in the
accompanying statement of operations to derive comprehensive income in
accordance with Statement of Financial Standards ("SFAS") No. 130, "Reporting
Comprehensive Income."

Segment Reporting

            In June 1997, SFAS 131, "Disclosure about Segments of an Enterprise
and Related Information," was issued. Operating segments, as defined in the
pronouncement, are components of an enterprise about which separate financial
information is available and that are evaluated regularly by management in
deciding how to allocate resources and assess performance. As of December 31,
2003, the Company had one operating segment, coal mining.

Cash and Cash Equivalents

         Cash and cash equivalents are stated at cost. Cash equivalents consist
of all highly liquid investments with maturities of three months or less when
acquired.

Marketable Securities

         The Company has adopted SFAS No. 115, "Accounting for Certain
Investments in Debt and Equity Securities," in accounting for securities. During
2003, the Company completely liquidated its' investment portfolio and recognized
a net gain on sales of marketable securities totaling $73,825.

Inventory

         Inventory consists of extracted coal available for delivery to
customers, and is valued at the lower of average cost or market. Coal inventory
costs include labor, supplies, equipment costs and operating overhead.

Property and Equipment

         Property and equipment are stated at cost. Expenditures for significant
renewals and improvements that extend estimated lives are capitalized.
Replacements, maintenance and repairs, which do not improve or extend the life
of the respective asset, are expensed as incurred. The Company removes the cost
and the related accumulated depreciation from the accounts for assets sold or
retired, and the resulting gains or losses are included in the results of
operations.

         Leased property and equipment meeting certain criteria is capitalized
and the present value of the related lease payments is recorded as a liability.

         Depreciation is provided using the straight-line method over the
estimated useful lives or lease life of the assets, ranging up to five years;
expense recorded for the eleven months ended December 31, 2003 was $240,440.

                                      F-10
<PAGE>




 Coal and Mineral Rights

     Significant  expenditures  incurred to acquire coal and mineral  rights are
capitalized at cost.  These costs  represent the  investment in mineral  rights,
including  capitalized mine development  costs, which are being mined or will be
mined.  Depletion and  amortization is computed on an actual tonnage mined basis
calculated  to amortize  costs  fully,  based on estimated  total  tonnage to be
mined.

Reclamation

     The Company has adopted the  provisions  of SFAS No. 143,  "Accounting  for
Asset  Retirement   Obligations."  SFAS  No.  143  generally  applies  to  legal
obligations associated with the retirement of long-lived assets that result from
the  acquisition,   construction,  development  and/or  normal  operation  of  a
long-lived asset.

         SFAS No. 143 requires recognition of expenses for eventual reclamation
of disturbed acreage remaining after mining production has been completed. A
liability is recorded for the present value of reclamation and mine closing
costs with a corresponding increase in the carrying value of coal and mineral
rights at the time a mine is permitted and commences operations. The carrying
costs are amortized and accrued expenditures accreted (in connection with
increases in the discounted liability) based on production from the mine
proportionate to the estimated total tonnage to be mined.

Loan Acquisition Costs

         Loan acquisition costs, related to convertible notes payable, are being
amortized using the straight-line method over the twelve-month term of the debt.

Asset Impairment

         If facts and circumstances suggest that a long-lived asset may be
impaired, the carrying value is reviewed. If this review indicates that the
value of the asset will not be recoverable, as determined based on projected
undiscounted cash flows related to the asset over its' remaining life, then the
carrying value of the asset is reduced to its estimated fair value.

Fair Value of Financial Instruments

         The carrying amounts for cash, accounts receivable, accounts payable
and accrued liabilities approximate fair value because of their immediate or
short-term maturities. The fair value of notes payable approximates fair value
because of the market rate of interest on the debt.

Income Taxes

         Deferred income taxes are based on temporary differences between the
financial statement and tax basis of assets and liabilities existing at each
balance sheet date using enacted tax rates for years during which taxes are
expected to be paid or recovered.

Net Loss Per Share

         The Company computes and presents loss per share in accordance with
SFAS No. 128, "Earnings Per Share". Basic earnings per share are computed based
upon the weighted average number of common shares outstanding during the period.
Warrants and convertible debt representing common shares of 1,597,250 and
6,520,022, respectively, were excluded from the average number of common shares
outstanding in the calculation because the effect of inclusion would be
anti-dilutive.

                                      F-11

<PAGE>





         All per share amounts reflect the retroactive effect of the April 2003
merger - See Footnote #6. A summary of weighted average shares follows:

        11 Months Ended December 31, 2003
        Shares Outstanding January 30, 2003 -
           SGI                                                        2,228,931
           NCC                                                       34,200,000
           Purchase of shares                                          (500,000)
        February 15, 2003 -
           Conversion of account payable                                150,876
        June 17, 2003 -
           Purchase of shares                                          (247,855)
        June 30, 2003 -
           Sale of shares                                               288,383
        July 7, 2003 -
           Sale of shares                                               290,620
        July 14, 2003 -
           Sale of shares                                               139,563
                                                                    ------------

              Total                                                  36,550,518
                                                                    ============

Concentration of Credit Risk and Major Customers

         SFAS No. 105, "Disclosure of Information about Financial Instruments
with Off-Balance-Sheet Risk and Financial Instruments with Concentrations of
Credit Risk", requires disclosure of significant concentration of credit risk
regardless of the degree of such risk.

         Financial instruments, which potentially subject the Company to
concentrations of credit risk, consist primarily of cash and accounts
receivable. Accounts receivable are from brokers or purchasers of the Company's
coal. The Company routinely performs credit evaluations of customers purchasing
on account and generally does not require collateral.

         The Company maintains the majority of its' cash deposits in one bank.
The deposits are guaranteed by the Federal Deposit Insurance Corporation
("FDIC") up to $100,000. At December 31, 2003, the Company's cash balance at the
bank was not in excess of the FDIC insurance limit.

         During 2003, the Company derived approximately 93% of total coal sales
from three customers.

Recent Accounting Pronouncements

         In June 2002, the Financial Accounting Standards Board ("FASB") issued
SFAS No.146, "Accounting for Costs Associated with Exit or Disposal Activities".
SFAS No. 146 addresses financial accounting and reporting for costs associated
with exit or disposal activities and nullifies Emerging Issues Task Force Issue
No. 94-3, "Liability Recognition for Certain Employee Termination Benefits and
Other Costs to Exit an Activity". SFAS No. 146 generally requires a liability
for a cost associated with an exit or disposal activity to be recognized and
measured initially at its fair value in the period in which the liability is
incurred. The pronouncement is effective for exit or disposal activities
initiated after December 31, 2002. The Company does not believe that the
adoption of SFAS No. 146 will have any impact on its' financial position or
results of operations.

                                      F-12
<PAGE>




         SFAS No. 147, "Acquisitions of Certain Financial Institutions," was
issued in December 2002 and is not expected to apply to the Company's current or
planned activities.


         In December 2002, the FASB approved SFAS No. 148, "Accounting for
Stock-Based Compensation - Transition and Disclosure - an amendment of FASB
Statement No. 123". SFAS No. 148 amends SFAS No. 123, "Accounting for
Stock-Based Compensation" to provide alternative methods of transition for a
voluntary change to the fair value based method of accounting for stock-based
employee compensation. In addition, SFAS No. 148 amends the disclosure
requirements of SFAS No. 123 to require prominent disclosures in both annual and
interim financial statements about the method of accounting for stock-based
employee compensation and the effect of the method used on reported results.
SFAS No. 148 is effective for financial statements for fiscal years ending after
December 15, 2002. The Company will continue to account for stock based
compensation using the methods detailed in its' stock-based compensation
accounting policy.

     In April 2003, the FASB approved SFAS No. 149,  "Amendment of Statement 133
on Derivative Instruments and Hedging Activities".  SFAS No. 149 is not expected
to apply to the Company's current or planned activities.

         In June 2003, the FASB approved SFAS No. 150, "Accounting for Certain
Financial Instruments with Characteristics of both Liabilities and Equity". SFAS
No. 150 establishes standards for how an issuer classifies and measures certain
financial instruments with characteristics of both liabilities and equity. This
Statement is effective for financial instruments entered into or modified after
May 31, 2003, and otherwise is effective at the beginning of the first interim
period beginning after June 15, 2003. SFAS No. 150 is not expected to have an
effect on the Company's financial position.

         In December 2003, the FASB issued a revised Interpretation No. 46,
"Consolidation of Variable Interest Entities". The interpretation clarifies the
application of Accounting Research Bulletin No. 51, "Consolidated Financial
Statements", to certain types of entities. The Company does not expect the
adoption of this interpretation to have any impact on its' financial statements.

3.       Lease Commitments

         During the second calendar quarter, the Company entered into short-term
capital lease agreements to acquire four mining vehicles with a combined
estimated fair value of $775,916, which approximates the present value of the
minimum lease payments. Amortization is included in depreciation expense.

         Additionally, the Company rents other mining equipment pursuant to
operating lease agreements, and made lease payments totaling $307,478 during
2003.

         In March 2003, the Company agreed to lease space in Georgia, on a
month-to-month basis, at $600 per month. In April 2003, the Company entered into
an agreement to lease its' Knoxville office for nine months at $1,800 per month,
with an option to renew for an additional nine months. Rental expense for these
lease commitments totaled approximately $22,200 through December 31, 2003.

                                      F-13
<PAGE>




         A summary of future minimum payments under non-cancelable capital and
operating lease agreements as of December 31, 2003 follows:

Year Ending                                       Operating
 December 31,                   Capital Leases    Leases                  Total
 ------------                   --------------    ------                  -----

2004                             $ 476,000        $ 138,000           $ 614,000
2005                                    -                -                    -
 Total minimum lease payments      476,000          138,000             614,000
 Less imputed interest             (17,197)              -              (17,197)
                                   -------          -------             --------
PV of minimum lease payments     $ 458,803        $ 138,000           $ 596,803
                                   =======          =======             ========


4.       Notes Payable

         In February 2003, the Company borrowed $150,000 from a trust owned by
the Chairman of the Board of the Company. This note accrues simple interest at
an annual rate of 8% and was to mature in February 2005. In August 2003, the
Company and Chairman agreed to extend the maturity date of such note for three
additional years. The new maturity date is now February 20, 2008. No additional
compensation was paid to the Chairman for such maturity extension. The note is
classified as a current liability in the accompanying balance sheet due to the
related party nature of the obligation.

         In March 2003, the Company issued convertible notes in the principal
amount of $3,194,902 to an unrelated party. These notes and related accrued
interest are convertible into common stock at $0.50 per share. In addition, the
note holder received warrants to purchase 1,597,250 shares of common stock at
$0.55 per share for two years. In September 2003, the Company borrowed $75,000
and $195,315 from the same entity. All of the notes payable accrue simple
interest at an annual rate of 12%, mature in March 2004, and have terms that
require an earlier payoff in the event of a successful equity or debt capital
financing. As of December 31, 2003, the four notes totaled approximately
$3,465,200, exclusive of accrued interest. In February 2004, these notes were
acquired by another investor and the maturity extended to March 2005. See
Footnote #9.

         In August 2003, the Company borrowed $250,000, in October 2003, the
Company borrowed $25,000, and in December 2003, the Company borrowed $30,000,
from Jenco Capital Corporation ("Jenco"), an entity partially owned by the
CEO/President of the Company. In December 2003, the Company borrowed $105,000
from the CEO/President of the Company. The notes payable accrue simple interest
at an annual rate of 8% and are payable on demand.

         In September 2003, the Company borrowed $80,000 from two unrelated
parties. The related notes payable accrue simple interest at an annual rate of
10%, mature in March 2004, and have terms that require an earlier payoff in the
event of a successful equity or debt capital financing. In November 2003, the
Company renegotiated the terms of indebtedness with these two unrelated parties,
such that the maturity was extended to March 7, 2004. As consideration for the
maturity extension, the principal amount payable to each note holder was
increased 10% and detachable warrants to purchase a total of 73,333 shares of
common stock at $.60 per share for two years. Specifically, one holder's
principal amount, which was originally due on October 15, 2003, was increased
from $30,000 to $33,000 as a result of the extension, and the other holder's
principal amount, which was originally due on November 11, 2003, was increased
from $50,000 to $55,000 as a result of the extension. The notes and related
accrued interest were converted into common stock in February 2004 at a
conversion rate of $0.55 per share. See Footnote #9.

                                      F-14
<PAGE>




         In November 2003, the Company borrowed $110,000 from two unrelated
parties. The related notes payable accrue simple interest at an annual rate of
10%, mature in March 2004, and have terms that require an earlier payoff in the
event of a successful equity or debt capital financing. The note holders were
also issued detachable warrants to purchase a total of 91,667 shares of common
stock at $.60 per share for two years. The notes and related accrued interest
were converted into common stock in February 2004 at a conversion rate of $0.55
per share. See Footnote #9.

5.       Income Taxes

         At December 31, 2003, the Company had a net operating loss carryforward
of approximately $3.3 million that may be offset against future taxable income
through 2023. These carryforwards are subject to review by the Internal Revenue
Service.

         The Company has fully reserved the $1.2 million tax benefit of the
operating loss carryforward, by a valuation allowance of the same amount,
because the likelihood of realization of the tax benefit cannot be determined.

         Temporary differences between the time of reporting certain items for
financial statement and tax reporting purposes consists primarily of
depreciation, depletion and accrued reclamation expenses.

6.       Equity Transactions

         On March 28, 2003, National Coal Corporation (Tennessee) entered into
an Agreement and Plan of Reorganization to acquire 34.2 million shares of
Southern Group International, Inc. common stock for all of National Coal
Corporation (Tennessee)'s outstanding common stock and $50,000 to retire 500,000
shares of SGI common stock. The $50,000 payment was made in March 2003 and
recorded as an administrative expense. The shares were exchanged on April 30,
2003. Immediately after the transaction, the former National Coal Corporation
(Tennessee) shareholders owned approximately 94.8% of SGI's common stock.
Coincident with the transaction, SGI changed its' name to National Coal
Corporation.

         The reorganization was recorded as a recapitalization effected by a
reverse merger wherein NCC/SGI is treated as the acquiree for accounting
purposes, even though it is the legal acquirer. Since SGI was a non-operating
entity with limited business activity, goodwill was not recorded. An unaudited
pro-forma summary of consolidated net liabilities on March 31, 2003 is set forth
below:
<TABLE>
<CAPTION>
<S>                               <C>                             <C>                    <C>

                                  NCC (Tennessee)                  NCC/SGI               Consolidated
Cash and equivalents                   $1,220,798                    $ 227                $ 1,221,025
Other current assets                        5,000                        -                      5,000
Other assets                            1,736,510                        -                  1,736,510
Notes payable and                                                                                   -
   current liabilities                 (3,585,766)                 (13,922)                (3,599,688)
                                        -------------               ----------              ----------
Net liabilities                        $ (623,458)                $(13,695)                $ (637,153)
                                        ===========                =========                ===========
</TABLE>

         The following unaudited pro forma consolidated results of operations
for the twelve months ended March 31, 2003 and 2002 (which includes NCC
(Tennessee) activity solely for the period since its inception to March 31,
2003) assumes the business combination had occurred April 1, 2001:

                                                    Year Ended March 31,
                                                 2003                  2002
                                                 ----                  ----
Revenues                                      $   -0-                $  -0-
                                               =======                ======
Net income (loss)                            $(804,705)             $(26,039)
                                              ==========             =========
Net income (loss) per share*                 $  (.02)               $ (.00)
                                              ==========             =========

*Based on 1,887,381 NCC/SGI shares outstanding prior to the reverse merger and
34,200,000 NCC/SGI shares issued as a result of the merger.

                                      F-15
<PAGE>




         In management's opinion, the unaudited pro forma results of operations
are not indicative of the actual results that would have occurred if the
acquisition had taken place at the beginning of the periods presented and are
not intended to be a projection of future results.

Issuance of Stock for Services

         In January 2003, a total of 15,350,000 shares of common stock were
granted to the four founding officer/directors of the Company for services. The
stock was valued at $153,500 ($0.01 per share) based on stock transactions for
cash with unrelated individuals (see below).

Issuance of Stock for Cash

         In January and February 2003, a total of 1,750,000 shares of common
stock were sold to individuals for $17,500 ($0.01 per share). In June and July
2003, a total of 1,350,000 shares were sold to investors for $270,000 ($0.20 per
share).

Convertible Debt and Warrants to Purchase Common Stock

         In March 2003, the Company issued two convertible notes payable for a
total of $3,194,902. The notes and related accrued interest are convertible into
common stock at $0.50 per share. The convertible note holders also received
warrants to purchase a total of 1,597,250 shares of common stock at $0.55 per
share for two years. As of December 31, 2003, none of the warrants had been
exercised. See Footnotes #4 & #9.

         In November 2003, the Company issued four note payable holders warrants
to purchase a total of 165,000 shares of common stock for two years at $.60 per
share (see Footnote #4). In the estimation of management, the value of the
warrants are not significant to the results of operations. As of December 31,
2003, none of the warrants have been exercised.

Other

         In June 2003, 421,450 shares of SGI common stock were re-purchased for
$21,073 and cancelled.

7.       Related Party Transactions

         On July 1, 2003, the Company sold mineral royalty rights for coal mined
on the Patterson Mountain portion of its' New River Tract for $75,156 to Jenco
Capital Corporation ("Jenco"), an entity partially owned by the CEO/President of
the Company. As consideration for the $75,156 received, the Company is obligated
to pay Jenco $2.00 per mined ton on the property. During the six months ended
December 31, 2003, the Company paid Jenco $59,572 in accordance with this
transaction.

         On August 1, 2003, the Company sold its interest in mineral royalty
rights received by the Company from U.S. Coal, Inc. for coal mined on the Smokey
Mountain portion of the New River Tract. The royalty was sold for $250,000 to
Jenco. As consideration for the $250,000 received, Jenco began receiving the
royalty payments from U.S. Coal. The Company recorded the transaction as
deferred revenue and recognizes revenue each month based on U.S. Coal's
production. As of December 31, 2003, royalties totaling $146,597 have been
recognized, leaving $103,403, which is included in deferred revenue.

                                      F-16

<PAGE>





         These transactions were completed by the Company with Jenco, a related
party, because (i) the Company needed a prompt capital infusion to ramp up coal
production, (ii) Jenco had available cash for the transaction, (iii) the Company
could not have developed another independent source for the capital without
considerable time delay due to lack of a production history, and (iv) the
Company had no knowledge of any outside sources for such capital. The Company
believes that given the time delay to search for capital and the cost of lost
opportunity, the terms of these transactions were acceptable because it afforded
immediate liquidity for operating purposes.

         On June 30, 2003, the Board of Directors assigned a ten-year, $0.25 per
ton royalty interest on all the coal sold from the Company's New River Tract, to
both the Chairman of the Board and the CEO/President. In the event any mineral
properties are sold prior to the end of the ten-year period, the obligation is
to be settled by paying 12 1/2% of the sales price to each individual. Pursuant
to the sale of mineral property rights to Jenco (see two paragraphs above), the
Company has recorded a liability to pay both the Chairman of the Board and the
CEO/President 12 1/2% of the sales price, a total of $81,289. The obligations
were paid in February 2004 and concurrently the June 30, 2003 agreements were
canceled. See Footnote #9.

         On February 26, 2003, NCC acquired mining equipment and certain other
intangible mining rights and information from Strata Coal, LLC ("Strata") for
$47,000 ($7,000 cash and a non-interest bearing promissory note) and assumption
of promissory notes payable to unrelated parties totaling $174,000. The Company
also assumed $14,875 of Strata's accounts payable. Strata is owned by the
Chairman of the Board and the CEO/President of NCC. Since the Strata transaction
involved related parties, primarily for intangible consideration, the $205,875
purchase price (exclusive of the mining equipment subsequently sold -see below),
has been expensed. Subsequent to March 31, 2003 the promissory notes (totaling
$214,000) were paid and on June 11, 2003 the mining equipment was sold to Jenco
for $30,000.

         On April 9, 2003, the Company acquired the coal mineral rights in fee
simple to the New River Tract assemblage for $1,270,000. In connection with this
transaction, the Company paid Kite, Bowen & Associates, PA $40,000 for legal
services. Mr. Kite is the managing partner of Kite, Bowen & Associates, PA, and
is a director of the Company.

         On March 31, 2003, the Company paid the Chairman of the Board and the
CEO/President $150,000 each for corporate organization and promotion activities.

         In October 2003, the Company loaned the Chief Financial Officer $15,000
at an annual interest rate of 3 1/2% and a maturity of 1 year. This loan was
made during the period of time that the CFO was performing his duties on an
interim basis and was not considered an officer of the Company. In February
2004, this loan, plus accrued interest, was paid in full.

         During 2003, the Company paid the law firm of Kite, Bowen & Associates,
PA a total of $45,000 for professional services rendered.

8.       Accrued Reclamation Expense

         The Company's estimated reclamation expenses on its' Patterson Mountain
Mine is based on engineering cost estimates developed by the U.S. Department of
the Interior, Office of Surface Mining ("OSM") in connection with obtaining the
mine permit. The obligation is discounted using an estimated credit-adjusted
risk-free rate of 12% and an estimated mine life of 12.6 years. Revisions to
estimated expenses could occur due to changes in future reclamation costs,
useful mine life or if federal or state regulators enact new reclamation
regulations.

                                      F-17
<PAGE>




         In the third quarter, 2003, the Company submitted the Patterson
Mountain Mine permit application to the OSM and remitted $257,500 for a
reclamation bond. On October 9, 2003, the OSM issued the permit to conduct
surface mining and approved the reclamation bond. During 2003, the Company
accrued Patterson Mountain Mine reclamation expenses as set forth below:

                         ------------------------------------------------------
       October 9, 2003 (issuance of permit)                            $ 57,312
                         ------------------------------------------------------
       Obligations incurred                                                -
                         ------------------------------------------------------
       Obligations settled                                                 -
                         ------------------------------------------------------
       Accretion expense                                                  7,047
                         ------------------------------------------------------
       Revision to estimates                                               -
                         ------------------------------------------------------
       December 31, 2003                                               $ 64,359
                                                                        ========

9.       Events Subsequent to December 31, 2003

Notes Payable

         Purchase and Extension of Convertible Notes

         In February 2004, Crestview Capital Master, LLC ("Crestview"), an
entity controlled by Crestview Capital Funds, directly purchased four
outstanding convertible notes payable of the Company, from an unrelated party,
in the aggregate principal amount of approximately $3,465,200, plus unpaid
interest. Concurrent with the repurchase of this debt, Crestview agreed to
extend the maturity date on all four notes to March 25, 2005 and to modify
certain provisions. The interest rate remains at 12% per annum. Two of the
original notes, in the aggregate principal amount of approximately $3.2 million,
each of which had a conversion option into common shares of the Company at a
conversion price of $0.50 per share, have been modified to preclude conversion
if the issuance would cause Crestview to own more that 9.99% of the then
outstanding equity in the Company when computed in accordance with Section 13d
of the Securities and Exchange Act of 1934. Crestview also purchased warrants
from the debt holder, which had been concurrently issued with the original two
notes. Those warrants allow for Crestview to purchase 1,597,250 shares of common
stock at a price per share equal to $0.55 until March 25, 2005.

         Conversion of Notes Payable

         In January 2004, four unrelated parties, holding an aggregate principal
amount of $198,000 of notes payable, accepted an offer from the Company to
convert all of their then outstanding principal and accrued interest into common
shares of the Company at a conversion price of $0.55 per share. Consequently,
the Company issued 368,399 shares collectively of its' common stock, with
360,000 representing the conversion of principal due, and 8,399 representing
accrued interest.

         Transactions with Related Parties

         In January 2004, the Company borrowed $10,000 from Jenco Capital
Corporation, an entity partially owned by the CEO/President of the Company. The
note payable accrues simple interest at an annual rate of 8% and is payable on
demand.

         In February 2004, the Company repaid (i) $105,000 in principal and
$1,024 in accrued interest to the CEO/President of the Company, and (ii) $65,000
in principal and $998 in accrued interest to Jenco.

                                      F-18
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Sale of Equity

         In February 2004, the Company sold an aggregate of 5,000,000 shares of
its common stock in a private placement, at a price per share of $0.55. The net
proceeds to the Company were $2,750,000. Crestview Capital Master, LLC, an
entity controlled by Crestview Capital Funds, purchased 2,600,000 of the
5,000,000 shares. This is Crestview's first investment with the Company. Three
unrelated accredited individual investors purchased the remaining 2,400,000
shares.

Cancellation of Royalty Agreements

         In February 2004, the Chairman of the Board and the CEO/President each
agreed to permanently cancel all future royalty payments which were to be made
to each of them by the Company pursuant to the June 30, 2003 ten-year, $0.25 per
ton royalty interest agreement related to all the coal sold from the New River
Tract.

Stock Option Plan

         In February 2004, the Company sought and received the approval of its
three largest shareholders, whose holdings collectively exceeded 80% of the then
outstanding shares of the Company's common stock, to establish a stock option
plan, to provide for the issuance of stock options to employees, consultants and
vendors. Such Plan has not been implemented and the Information Statement
thereon has not been distributed to Shareholders and the Plan is not yet
effective. The stock option plan (the "Plan") will allow for the issuance of
options to purchase up to an aggregate of 6 million shares of Company's common
stock to be distributed pursuant to the rules and regulations of the Plan. To
date, no options have been distributed out of the Plan.

                                      F-19