S-1/A
As filed with the Securities and Exchange Commission on
January 9, 2006
Registration
No. 333-129030
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Amendment No. 3 to
Form S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
ALPHA NATURAL RESOURCES, INC.
(Exact name of registrant as specified in its charter)
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Delaware |
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1222 |
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02-0733940 |
(State of Incorporation) |
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(Primary Standard Industrial
Classification Code Number) |
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(I.R.S. Employer Identification No.) |
One Alpha Place
P.O. Box 2345
Abingdon, VA 24212
(276) 619-4410
(Address, including zip code, and telephone number, including
area code, of registrants principal executive offices)
Vaughn R. Groves, Esq.
Vice President and General Counsel
Alpha Natural Resources, Inc.
One Alpha Place
P.O. Box 2345
Abingdon, VA 24212
(276) 619-4410
(Name, address, including zip code, and telephone number,
including area code, of agent for service)
With copies to:
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James L. Palenchar, Esq.
Polly S. Swartzfager, Esq.
Bartlit Beck Herman Palenchar & Scott LLP
1899 Wynkoop Street, 8th Floor
Denver, CO 80202
Ph: (303) 592-3100
Fax: (303) 592-3140 |
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Peter M. Labonski, Esq.
Latham & Watkins LLP
885 Third Avenue, Suite 1000
New York, New York 10022-4802
Ph: (212) 906-1200
Fax: (212) 751-4864 |
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Edward P. Tolley III, Esq.
Joshua Ford Bonnie, Esq.
Simpson Thacher & Bartlett LLP
425 Lexington Avenue
New York, New York 10017-3954
Ph: (212) 455-2000
Fax: (212) 455-2502 |
If any of the securities being registered on this form are to be
offered on a delayed or continuous basis pursuant to
Rule 415 under the Securities Act of 1933, check the
following
box. o
If this form is filed to register additional securities for an
offering pursuant to Rule 462(b) under the Securities Act,
check the following box and list the Securities Act registration
statement number of the earlier effective registration statement
for the same
offering. o
If this form is a post-effective amendment filed pursuant to
Rule 462(c) under the Securities Act, check the following
box and list the Securities Act registration statement number of
the earlier effective registration statement for the same
offering. o
If this form is a post-effective amendment filed pursuant to
Rule 462(d) under the Securities Act, check the following
box and list the Securities Act registration statement number of
the earlier effective registration statement for the same
offering. o
If delivery of the prospectus is expected to be made pursuant to
Rule 434, check the following
box. o
CALCULATION OF REGISTRATION FEE
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Proposed Maximum |
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Proposed Maximum |
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Amount of |
Title of Each Class of |
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Amount to be |
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Offering |
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Aggregate |
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Registration |
Securities to be Registered |
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Registered(1) |
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Price Per Share(2) |
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Offering Price(2) |
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Fee |
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Common stock, par value $0.01 per share
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14,163,527 shares |
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$23.25 |
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$329,302,003 |
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$38,605.82(3) |
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(1) |
Includes shares of common stock that the underwriters have the
option to purchase to cover over-allotments, if any. |
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(2) |
Estimated solely for the purpose of calculating the registration
fee under Rule 457(c) of the Securities Act of 1933, as
amended, based on the average of high and low prices of the
common stock on November 29, 2005, as reported on the
New York Stock Exchange. |
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(3) |
Previously paid. |
The Registrant hereby amends this Registration Statement on
such date or dates as may be necessary to delay its effective
date until the Registrant shall file a further amendment which
specifically states that this Registration Statement shall
thereafter become effective in accordance with Section 8(a)
of the Securities Act of 1933 or until this Registration
Statement shall become effective on such date as the Commission,
acting pursuant to said Section 8(a), may determine.
The information in this prospectus is not
complete and may be changed. The selling stockholders may not
sell these securities until the registration statement filed
with the Securities and Exchange Commission is effective. This
prospectus is not an offer to sell these securities and it is
not soliciting offers to buy these securities in any state where
the offer or sale is not permitted.
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SUBJECT TO COMPLETION. DATED
JANUARY 6, 2006
PROSPECTUS
12,316,110 Shares
(ALPHA NATURAL RESOURCES LOGO)
Alpha Natural Resources, Inc.
Common Stock
The selling stockholders named in this prospectus are selling
12,316,110 shares of our common stock. We will not receive
any proceeds from the sale of the shares in this offering.
Our common stock is listed on the New York Stock Exchange under
the symbol ANR. On January 5, 2006, the last
reported sale price of our common stock was $19.37 per
share.
To the extent that the underwriters sell more than
12,316,110 shares of common stock, the underwriters have
the option for a period of 30 days after the date of this
prospectus to purchase up to an additional 1,847,417 shares
of common stock from the selling stockholders at the public
offering price less the underwriting discounts and commissions.
Investing in our common stock involves risks. See Risk
Factors beginning on page 20.
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Public | |
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Proceeds, before | |
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selling stockholders | |
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Per Share
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Total
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Neither the Securities and Exchange Commission nor any other
regulatory body has approved or disapproved of these securities
or passed upon the accuracy or adequacy of this prospectus. Any
representation to the contrary is a criminal offense.
The underwriters expect to deliver the shares to purchasers
on ,
2006.
Morgan Stanley Citigroup UBS Investment Bank
Bear, Stearns & Co.
Inc.
Davenport & Company LLC
,
2006
You should rely only on the information contained in this
prospectus. We have not authorized anyone to provide you with
different information. The selling stockholders are offering to
sell, and seeking offers to buy, shares of our common stock only
in jurisdictions where offers and sales are permitted.
TABLE OF CONTENTS
No action is being taken in any jurisdiction outside the United
States to permit a public offering of the common stock or
possession or distribution of this prospectus in that
jurisdiction. Persons who come into possession of this
prospectus in jurisdictions outside the United States are
required to inform themselves about and to observe any
restrictions as to this offering and the distribution of this
prospectus applicable to those jurisdictions.
Unless indicated otherwise, the information included in this
prospectus assumes no exercise by the underwriters of their
over-allotment option to purchase up to 1,847,417 additional
shares from the selling stockholders.
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PROSPECTUS SUMMARY
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This summary does not contain all of the information you
should consider in making your investment decision. Before
investing in our common stock, you should carefully read this
entire document, including our combined historical and pro forma
financial statements and accompanying notes included elsewhere
in this prospectus. You should also carefully consider, among
other things, the matters discussed under Risk
Factors and Managements Discussion and
Analysis of Financial Condition and Results of
Operations. |
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Unless the context otherwise indicates, as used in this
prospectus, the terms Alpha, we,
our, us and similar terms refer to
(1) the majority of the Virginia coal operations of
Pittston Coal Company, a subsidiary of The Brinks Company
(our Predecessor) with respect to periods on and
prior to December 13, 2002, (2) ANR Fund IX
Holdings, L.P. and Alpha NR Holding, Inc. and subsidiaries on a
combined basis with respect to periods from and after
December 14, 2002 until the completion of our Internal
Restructuring as defined and described below, and (3) Alpha
Natural Resources, Inc. and its consolidated subsidiaries with
respect to periods from and after the completion of our Internal
Restructuring. |
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All references to Alpha Natural Resources, Inc., including
the business description, operating data and financial data,
exclude the former Colorado operations of our NatCoal, LLC and
GTTC, LLC subsidiaries (collectively, NKC), which
were sold to a third party on April 14, 2005 and are
accounted for herein as discontinued operations. References to
pro forma financial information reflect (1) for statement
of operations and other data, the consummation of our Internal
Restructuring, 2004 Financings and IPO, as defined and described
below under Alpha Summary Historical and Pro Forma
Financial Data, and the 2005 Financing and Nicewonder
Acquisition as defined and described below under
Nicewonder Acquisition, in each case as if these events
had occurred on January 1, 2004 and (2) for balance
sheet data, the consummation of the 2005 Financing and
Nicewonder Acquisition, in each case as if these events had
occurred on September 30, 2005. See Unaudited Pro
Forma Financial Information. |
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Alpha Natural Resources
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We are a leading Appalachian coal producer. Our reserves
primarily consist of high Btu, low sulfur steam coal that is
currently in high demand in U.S. coal markets and
metallurgical coal that is currently in high demand in both U.S.
and international coal markets. We produce, process and sell
steam and metallurgical coal from eight regional business units,
which, as of November 1, 2005, are supported by 44 active
underground mines, 25 active surface mines and 11 preparation
plants located throughout Virginia, West Virginia, Kentucky and
Pennsylvania. We are also actively involved in the purchase and
resale of coal mined by others, the majority of which we blend
with coal produced from our mines, allowing us to realize a
higher overall margin for the blended product than we would be
able to achieve selling these coals separately. |
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Steam coal, which is primarily purchased by large utilities and
industrial customers as fuel for electricity generation,
accounted for approximately 62% of our coal sales volume in the
first nine months of 2005 and 63% of our 2004 coal sales volume.
The majority of our steam coal sales volume in the first nine
months of 2005 and during 2004 consisted of high Btu (above
12,500 Btu content per pound), low sulfur (sulfur content of
1.5% or less) coal, which typically sells at a premium to
lower-Btu, higher-sulfur steam coal. Metallurgical coal, which
is used primarily to make coke, a key component in the steel
making process, accounted for approximately 38% of our coal
sales volume in the first nine months of 2005 and 37% of our
2004 coal sales volume. Metallurgical coal generally sells at a
premium over steam coal because of its higher quality and its
value in the steelmaking process as the raw material for coke.
Under current market conditions, we are able to market a
significant portion of our higher quality steam coal as
metallurgical coal. |
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During the first nine months of 2005, we sold a total of
18.9 million tons of steam and metallurgical coal and
generated revenues of $1,127.5 million, EBITDA of
$88.4 million and net income of $8.8 million. |
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We define and reconcile EBITDA, and explain its importance, in
note (1) to the table under Alpha Summary
Historical and Pro Forma Financial Data. In 2004, we sold
a total of 25.3 million tons of steam and metallurgical
coal and generated revenues of $1,252.7 million, EBITDA of
$99.5 million and net income of $20.0 million. Our
coal sales during the first nine months of 2005 consisted of
14.9 million tons of produced and processed coal, including
1.0 million tons purchased from third parties and processed
at our processing plants or loading facilities prior to resale,
and 4.0 million tons of purchased coal that we resold
without processing. Our coal sales during 2004 consisted of
18.9 million tons of produced and processed coal, including
0.9 million tons purchased from third parties and processed
at our processing plants or loading facilities prior to resale,
and 6.4 million tons of purchased coal that we resold
without processing. We sold a total of 5.0 million tons of
purchased coal during the first nine months of 2005 and
7.3 million tons in 2004, of which approximately 70% and
81%, respectively, was blended with coal produced from our mines
prior to resale. Approximately 44% of our sales revenue in the
first nine months of 2005 and 47% of our sales revenue in 2004
was derived from sales made outside the United States, primarily
in Japan, Canada, Brazil, Korea and several countries in Europe. |
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As of July 31, 2005, on a pro forma basis giving effect to
the Nicewonder Acquisition described below, we owned or leased
518.9 million tons of proven and probable coal reserves. Of
our total proven and probable reserves, approximately 90% are
low sulfur reserves, with approximately 60% having sulfur
content below 1.0%. Approximately 92% of our total proven and
probable reserves have a high Btu content. We believe that our
total proven and probable reserves will support current
production levels for more than 20 years.
Nicewonder Acquisition
On October 26, 2005, we completed the acquisition of
certain privately held coal reserves and operations in southern
West Virginia and southwestern Virginia (the Nicewonder
Acquisition) for an aggregate purchase price of
$315.2 million, consisting of cash at closing in the amount
of $35.2 million, a cash tax payment of $1.9 million
to be made to the sellers in April 2006, estimated transaction
costs of $3.9 million, $221.0 million principal amount
of promissory installment notes of one of our indirect, wholly
owned subsidiaries, of which $181.1 million was paid on
November 2, 2005 and $39.9 million is due on
January 15, 2006, and 2,180,233 shares of our common
stock valued at approximately $53.2 million for accounting
purposes. For this purpose, the value of the common stock issued
was based on the average closing prices of our common stock for
the five trading days surrounding October 20, 2005, the
date the number of shares to be issued under the terms of the
acquisition agreement became fixed without subsequent revision.
The final cash purchase price is subject to certain working
capital and other adjustments. The Nicewonder Acquisition
consisted of the purchase of the outstanding capital stock of
White Flame Energy, Inc., Twin Star Mining, Inc. and Nicewonder
Contracting, Inc., the equity interests of Powers Shop, LLC and
Buchanan Energy, LLC and substantially all of the assets of Mate
Creek Energy of W. Va., Inc. and Virginia Energy Company, and
the acquisition of Premium Energy, Inc. by merger (together
referred to as the Nicewonder Coal Group). In
connection with the Nicewonder Acquisition, we also agreed to
make royalty payments to the former owners of the acquired
companies in the amount of $0.10 per ton of coal mined and sold
from White Flame Energys surface mine no. 10.
For the fiscal year ended December 31, 2004 and the nine
months ended September 30, 2005, the Nicewonder Coal Group
produced approximately 3.8 million and 2.9 million
tons of coal, respectively. For the fiscal year ended
December 31, 2004 and the nine months ended
September 30, 2005, the Nicewonder Coal Group generated
revenues of approximately $144.6 million and
$156.9 million, respectively, and EBITDA of
$37.4 million and $51.9 million, respectively. EBITDA
for the Nicewonder Coal Group is reconciled in note
(1) under Nicewonder Summary Historical
Financial Data.
The assets of the Nicewonder Coal Group include approximately
26.7 million tons of proven and probable reserves as of
July 31, 2005, three surface mines and related equipment,
as well as a road construction and coal recovery business. As of
September 30, 2005, the Nicewonder Coal Group had 394
employees, all of whom were employed on a union-free basis. Don
Nicewonder, the former principal owner of the Nicewonder Coal
Group, entered into a three-year consulting agreement with Alpha
upon closing of
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the acquisition. The operations acquired from the Nicewonder
Coal Group constitute a new eighth business unit, although we
may eventually integrate these operations into our seven other
existing business units.
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On October 26, 2005, in connection with the Nicewonder
Acquisition, we entered into a new $525.0 million credit
facility (the 2005 Financing) consisting of a
$250.0 million term loan facility and a $275.0 million
revolving credit facility. We used the net proceeds of the term
loan facility and a portion of the proceeds from drawings under
the revolving credit facility to finance the Nicewonder
Acquisition and to refinance our then-existing
$175.0 million credit facility, which we refer to in this
prospectus as our prior credit facility. |
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Competitive Strengths
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We believe that the combination of the following competitive
strengths distinguishes us from our competitors. |
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We provide a comprehensive range of steam and metallurgical
coal products that are in high demand. Our reserves enable
us to provide customers with coal products that are in high
demand including high Btu, low sulfur steam coal,
and low, medium and high volatile metallurgical coal. Steam coal
customers value high Btu coal because it fuels electricity
generation more efficiently than lower energy content coal. In
addition, the demand for clean burning, low sulfur coal has
grown significantly since the implementation of sulfur emission
restrictions mandated by the Clean Air Act. Metallurgical coal
customers require precise coal characteristics to meet their
coke production specifications and generally value low volatile
metallurgical coal more highly than other categories of
metallurgical coal. |
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Our flexible mining operations and diversified asset base
allow us to manage costs while capitalizing on market
opportunities. Our 69 active mines, 11 preparation plants
and eight regional business units are supported by flexible and
cost-effective use of our mining equipment and personnel. Our
mining equipment is interchangeable and can be redirected easily
at a relatively low cost, providing us with flexibility to
respond to changing geologic, operating and market conditions.
The diversity of our portfolio of mines and preparation plants
allows us to move resources between existing or new operations
and limits our mine concentration risk. |
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Our ability to provide customized product offerings creates
valuable market opportunities, strengthens our customer
relationships and improves profitability. We have a
customer-focused marketing strategy that, combined
with our comprehensive range of coal product offerings and
established marketing network, enables us to customize our coal
deliveries to a customers precise needs and
specifications. The products we sell to our customers will often
be a blend of internally produced coal and coal we have
purchased from third parties, in contrast to the more
traditional approach of only offering coal produced from captive
mines. We believe our commitment to providing high quality coal
products designed to our customers specifications enables
us to maintain strong customer relationships while maximizing
the value of our coal reserves. |
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Our primary operating focus is the Appalachian region, the
region with the most producer-favorable coal supply and demand
dynamics in the United States. Our operations are focused on
Central and Northern Appalachia, which accounted for
approximately 72% and 28%, respectively, of the coal produced
from our mines during 2004. The Appalachian region has produced
declining supplies of coal in recent years while regional
demand, already the highest in the United States based on tons
consumed, is expected to increase due to growth in regional
demand for electricity. We believe these trends in Appalachian
coal supply and demand, the high quality of Appalachian coal and
the lower transportation costs that result from the proximity of
Appalachian producers and customers create favorable pricing
dynamics that provide us with an advantage over producers from
other regions. |
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Our Central Appalachian mining expertise provides us with
significant regional growth opportunities. Our focus on the
Appalachian region has allowed us to develop expertise in
efficiently mining Central
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Appalachian reserves. Furthermore, we have developed both a good
understanding of the regions transportation infrastructure
and a favorable reputation with the regions property
owners, coal industry operators and employee base.
Our comparatively low amount of long-term reclamation and
employee-related liabilities provides us with financial
flexibility. As of September 30, 2005, on a pro forma
basis giving effect to the Nicewonder Acquisition, we had total
accrued reclamation liabilities of $48.9 million,
self-insured workers compensation liabilities of
$6.5 million and post-retirement obligations of
$22.2 million, and we had no pension liabilities and
minimal black lung liabilities. We believe the amount of these
liabilities are among the lowest of the publicly-traded
U.S. coal producers. In addition, because over 91% of our
approximately 3,240 employees are employed by our
subsidiaries on a union-free basis as of November 1, 2005,
and approximately 95% of our coal production during 2004 was
produced from mines operated by union-free employees, we are
better able to minimize the types of employee-related
liabilities commonly associated with union-represented mines.
Our management team has extensive coal industry experience
and has successfully integrated a number of acquisitions.
Our senior executives have, on average, more than 20 years
of experience in the coal industry, largely in the Appalachian
region, and they have substantial experience in increasing
productivity, reducing costs, implementing our marketing
strategy and coal blending capabilities, improving safety, and
developing and maintaining strong customer and employee
relationships. In addition to their operating strengths, the
majority of our senior executives have significant experience in
identifying, acquiring and integrating acquired coal companies
into existing organizations.
Business Strategy
We believe that we are well-positioned to enhance our position
as a leading Appalachian coal producer by continuing to
implement our strategy, which consists of the following key
components:
Achieve premium pricing and optimum efficiency in contract
fulfillment. We intend to continue to use our diversified
operating strategy, coal blending capabilities, market knowledge
and strong marketing organization to identify and capitalize on
opportunities to generate premium pricing for our coal and to
achieve optimum efficiency in fulfillment of coal contracts. As
of December 31, 2005, approximately 12%, 54% and 77%,
respectively, of our planned production for 2006, 2007 and 2008,
including production from the operations we acquired in the
Nicewonder Acquisition, was uncommitted and was not yet priced,
which we believe provides us with significant price certainty in
the short-term while maintaining uncommitted planned production
that allows us to take an opportunistic approach to selling our
coal.
Maximize profitability of our mining operations. We
continuously reassess our reserves, mines and processing and
loading facilities in an effort to determine the optimum
operating configuration that maximizes our profitability,
efficient use of operating assets and return on invested
capital. We intend to continue to optimize the profitability of
our mining operations through a series of initiatives that
include:
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increasing production levels where we determine that such
increased production can be profitably achieved; |
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leveraging our product offerings, blending capabilities and
marketing organization to realize higher margins from our sales; |
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deploying our resources against the most profitable
opportunities available in our asset portfolio; |
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consolidating regional operations and increasing the utilization
of our existing preparation plants and loading facilities; |
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maintaining our focus on safety and implementing safety measures
designed to keep our workforce injury free; and |
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coordinating company-wide purchasing activities with major
vendors to provide materials and supplies at lower overall cost. |
Pursue strategic value-creating acquisitions. We have
successfully acquired and integrated businesses into our
operations, and we intend to continue to expand our business and
coal reserves through acquisitions of attractive, strategically
positioned assets. Although we intend to concentrate our efforts
in Appalachia, where we believe there remain attractive
acquisition opportunities, we will continue to evaluate
opportunities in other regions that meet our acquisition
criteria. We employ what we believe is a disciplined acquisition
strategy focused on acquiring coal and coal-related operations
and assets at attractive valuations. We believe that our recent
acquisition of the Nicewonder Coal Group is consistent with this
strategy.
Maintain a strong safety, labor relations and environmental
record. One of our core values is protecting the health and
welfare of our employees by designing and implementing high
safety standards in the workplace. We also aim to preserve the
positive relationship we have developed with our employees.
Similarly, we aim to adhere to high standards in protecting and
preserving the environment in which we operate.
Risks Related to our Business and Strategy
Our ability to execute our strategy is subject to the risks that
are generally associated with the coal industry. For example,
our profitability could decline due to changes in coal prices or
coal consumption patterns, as well as unanticipated mine
operating conditions, loss of customers, changes in our ability
to access our coal reserves and other factors that are not
within our control. Furthermore, the heavily regulated nature of
the coal industry imposes significant actual and potential costs
on us, and future regulations could increase those costs or
limit our ability to produce coal.
We are also subject to a number of risks related to our
competitive position and business strategies. For example, our
acquisitive business strategy exposes us to the risks involved
in consummating and integrating acquisitions, including the risk
that in a future acquisition we could assume more long-term
liabilities relative to the value of the acquired assets than we
have assumed in our previous acquisitions, thereby reducing our
competitive strength with regard to our level of long-term
liabilities. In addition, our focus on the Central and Northern
Appalachian regions exposes us to the risks of operating in
these regions, including higher costs of production as compared
to other coal-producing regions and more costly and restrictive
permitting, licensing and other environmental and regulatory
requirements. For additional risks relating to our business and
this offering, see Risk Factors beginning on
page 20 of this prospectus.
Coal Market Outlook
According to traded coal indices and reference prices, U.S. and
international coal demand is currently strong. Coal pricing
increased in 2004 and has remained at historically high levels
since then in each of our coal production markets. We believe
that the current strong fundamentals in the U.S. coal
industry result primarily from:
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stronger industrial demand following a recovery in the
U.S. manufacturing sector, evidenced by the most recent
estimate of 3.8% real GDP growth in the third quarter of 2005,
as reported by the Bureau of Economic Analysis; |
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relatively low customer stockpiles, estimated by the
U.S. Energy Information Administration (EIA) to
be approximately 105.6 million tons at the end of July,
2005, down 5.8% from the same period in the prior year; |
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declining coal production in Central Appalachia, including an
average annual decline of 4.9% in Central Appalachian coal
production volume from January 1, 2001 through
December 31, 2004; |
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capacity constraints of U.S. nuclear-powered electricity
generators, which operated at an average utilization rate of
90.5% in 2004, up from 73.8% in 1994, as estimated by the EIA; |
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high current and forward prices for natural gas and heating oil,
the primary fuels for electricity generation, with spot prices
as of January 5, 2006, for natural gas and heating oil at
$9.29 per million Btu and $1.76 per gallon,
respectively, as reported by Bloomberg L.P.; and |
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increased international demand for U.S. coal for
steelmaking, driven by global economic growth, high ocean
freight rates and the weak U.S. dollar. |
U.S. spot steam coal prices have increased significantly
since mid-2003, particularly for coals sourced in the eastern
United States. The table below describes the percentage increase
in year-over-year average
year-to-date reference
prices for coal as of November 21, 2005, according to
Platts Research and Consulting (Platts), in the
regions where we produce our coal, and the percentage of our
produced and processed coal sales volume during 2004 by region:
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Increase in Average | |
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Percentage of Produced and | |
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Reference Prices | |
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Processed Coal Sales in 2004 | |
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Central Appalachia
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8.5% |
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72.2% |
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Northern Appalachia
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13.5% |
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27.8% |
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We expect near-term volume growth in U.S. coal consumption
to be driven by greater utilization at existing coal-fired
electricity generating plants, which operated at an estimated
72% of capacity in 2004, according to Platts. If existing
U.S. coal fueled plants operate at estimated potential
utilization rates of 85%, we believe they would consume
approximately 185 million additional tons of coal per year,
which represents an increase of approximately 16% over current
coal consumption.
We expect longer-term volume growth in U.S. coal
consumption to be driven by the construction of new coal-fired
plants. The National Energy Technology Laboratory
(NETL), an arm of the U.S. Department of Energy
(the DOE), projects that more than 100,000 megawatts
of new coal-fired electric generation capacity will be
constructed in the United States by 2025. The NETL has
identified 124 coal-fired plants, representing
73,000 megawatts of electric generation capacity, that have
been proposed and are currently in various stages of
development. The DOE projects that approximately 70 of these
proposed coal-fired plants, representing approximately
43,000 megawatts of electric generation capacity, will be
completed and will begin consuming coal to produce electricity
by the end of 2010.
The current pricing environment for U.S. metallurgical coal
is also strong in both the domestic and seaborne export markets.
Demand for metallurgical coal in the United States has increased
due to a recovery in the U.S. steel industry. In addition
to increased demand for metallurgical coal in the United States,
demand for metallurgical coal has increased in international
markets. According to the International Iron and Steel
Institute, global steel consumption increased by 8.8% during
2004 over the 2003 level, Chinese steel consumption increased
approximately 11% in 2004 over 2003, and global apparent steel
demand is projected to have increased by 2.7% in 2005, with 2005
apparent steel demand in China increasing by 10.3%. BHP
Billiton, a major Australian producer, reported a 53% increase
in average realized metallurgical coal prices for fiscal year
2005 over the prior fiscal year, and Fording Canadian Coal
Trust, a major Canadian producer, reported an increase of
approximately 83% in average metallurgical coal sales price for
the nine months ended September 30, 2005 over the same
period in 2004. The tightening supply of metallurgical coal in
global markets has been due in part to supply disruptions in
Australia, the worlds largest coal exporter, and the
decision by China, the worlds second largest coal
exporter, to restrict its metallurgical coal exports in order to
satisfy domestic demand. The table below describes average sale
prices, according to Platts, for low volatile metallurgical coal
at the Hampton Roads, Virginia export terminals, through which
we ship the great majority of our metallurgical coal exports and
which
6
collectively constitute the highest volume export facility for
U.S. metallurgical coal production, and the percentage
increase or decrease in prices year-over-year:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Sale Prices per Ton for Low Volatile Metallurgical Coal | |
|
|
at Hampton Roads, Virginia Export Terminals | |
|
|
| |
|
|
|
|
Percentage) | |
|
|
IncreaseYear-Over-Year | |
|
|
(decrease | |
|
|
| |
September 30, 2004
|
|
$ |
135.00 |
|
|
|
September 30, 2005 |
|
|
$ |
130.00 |
|
|
|
(4 |
)% |
April 5, 2004
|
|
$ |
135.00 |
|
|
|
April 1, 2005 |
|
|
$ |
135.00 |
|
|
|
0 |
% |
January 12, 2004
|
|
$ |
71.50 |
|
|
|
January 3, 2005 |
|
|
$ |
137.50 |
|
|
|
92 |
% |
October 6, 2003
|
|
$ |
52.00 |
|
|
|
October 4, 2004 |
|
|
$ |
135.00 |
|
|
|
160 |
% |
Recent Developments
On December 9, 2005, we announced a downward adjustment to
our outlook with respect to our expected results for 2005. Based
on recent developments, we expect revenue for the fourth quarter
of 2005 to be negatively impacted by delays in certain exports
of metallurgical coal as a result of late-arriving vessels and
customer deferrals. Limited rail capacity and customer changes
to delivery schedules have also curtailed shipments to utilities
in the north central and southeastern United States and Canada
as well as to our export facility in Norfolk, Virginia. These
and other factors are expected to result in net income for 2005
to be in the range of $10.0 million to $20.0 million
and EBITDA for 2005 to be in the range of $128.0 million to
$138.0 million. We expect our net income and EBITDA for
2005 to include a charge for minority interest of approximately
$3.0 million and a charge for stock-based compensation
expense related to our initial public offering of approximately
$46.6 million. Our earnings expectations assume that
interest expense, net, will be approximately $29.0 million,
income tax expense will be approximately $18.0 million, and
depreciation, depletion and amortization will be approximately
$72.0 million. Our expectations for 2005 are based on our
unaudited results for the nine months ended
September 30, 2005, our preliminary unaudited monthly
results for October and November, which are subject to review
procedures and final reconciliations and adjustments in
connection with our year-end audit, and on managements
projections for December which may differ materially from actual
results. We also announced on December 9, 2005 that we
anticipate that cost pressures will persist in 2006, including
higher costs for purchased coal, contractor mining, trucking and
general mining supplies. Variable costs such as royalties and
severance taxes are also expected to rise in 2006 in parallel
with rising sales volumes. See Managements
Discussion and Analysis of Financial Condition and Results of
Operations Coal Pricing Trends and
Uncertainties. Our expected results for 2005 and our
expectations with respect to cost pressures in 2006 are
forward-looking statements within the meaning of
Section 27A of the Securities Act of 1933 and
Section 21E of the Securities Exchange Act of 1934 and are
intended to come within the safe harbor protection provided by
those sections. See Special Note Regarding Forward-Looking
Statements.
7
The Offering
|
|
|
|
Shares of common stock offered by the selling stockholders: |
|
12,316,110 shares |
|
|
|
Shares of common stock outstanding after this offering |
|
64,420,414 shares |
|
|
Use of proceeds |
|
We will not receive any of the proceeds from the sale of shares
by the selling stockholders. The selling stockholders will
receive all the net proceeds from the sale of shares of common
stock offered by this prospectus. |
|
New York Stock Exchange symbol |
|
ANR |
Unless we specifically state otherwise, all information in this
prospectus:
|
|
|
|
|
|
assumes no exercise by the underwriters of their option to
purchase up to 1,847,417 additional shares from the selling
stockholders; and |
|
|
|
|
|
excludes 3,837,529 shares of our common stock reserved for
issuance and not yet issued under our existing long-term
incentive plans as of January 1, 2006, of which
1,253,593 shares of our common stock are issuable upon the
exercise of outstanding options as of January 1, 2006. |
|
Additional Information
Our principal executive office is located at One Alpha Place,
P.O. Box 2345, Abingdon, Virginia 24212 and our
telephone number is
(276) 619-4410.
Risk Factors
Investing in our common stock involves substantial risks. You
should carefully consider the information in the Risk
Factors section and all other information included in this
prospectus before investing in our common stock.
8
Alpha Summary Historical and Pro Forma Financial Data
ANR Holdings, LLC (ANR Holdings) was formed in
December 2002 by First Reserve Fund IX, L.P. and ANR
Fund IX Holdings, L.P. (referred to as the First
Reserve Stockholders or collectively with their
affiliates, First Reserve) and our management to
serve as the top-tier holding company of the Alpha Natural
Resources organization. On December 13, 2002, we acquired a
majority of the Virginia coal operations of Pittston Coal
Company, a subsidiary of The Brinks Company, our
Predecessor. On January 31, 2003, we acquired the
membership interests of Coastal Coal Company, LLC and certain
affiliates (Coastal Coal Company). On March 11,
2003, we acquired American Metals & Coal International,
Inc.s (AMCI) U.S. coal production and
marketing operations. We refer to the U.S. coal operations
and marketing assets we acquired from AMCI as
U.S. AMCI. On November 17, 2003, we
acquired the assets of Mears Enterprises, Inc. and affiliated
entities (collectively, Mears) for
$38.0 million. On May 18, 2004, our subsidiary, Alpha
Natural Resources, LLC and its wholly-owned subsidiary, Alpha
Natural Resources Capital Corp., issued $175.0 million
principal amount of 10% senior notes due 2012, and on
May 28, 2004, we entered into a $175.0 million credit
facility (together referred to as the 2004
Financings). On February 11, 2005, Alpha Natural
Resources, Inc. succeeded to the business and became the
indirect parent entity of ANR Holdings in a series of internal
restructuring transactions which we refer to collectively as the
Internal Restructuring, and on February 18,
2005, Alpha Natural Resources, Inc. completed the initial public
offering of 33,925,000 shares of its common stock for an
aggregate offering price of $644.6 million, which we refer
to herein as the IPO.
The following summary historical financial data as of
December 31, 2004 and 2003, for the years ended
December 31, 2004 and 2003 and for the period from
December 14, 2002 through December 31, 2002, have been
derived from the combined financial statements of ANR
Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
subsidiaries (the owners of a majority of the membership
interests of ANR Holdings prior to the Internal Restructuring),
and the related notes, included elsewhere in this prospectus,
which have been audited by KPMG LLP (KPMG), an
independent registered public accounting firm. The summary
historical financial data as of December 31, 2002 have been
derived from the audited combined balance sheet of ANR
Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
subsidiaries not included in this prospectus. The summary
historical financial data for the period from January 1,
2002 through December 13, 2002 have been derived from our
Predecessors combined financial statements and related
notes thereto, included elsewhere in this prospectus, which have
been audited by KPMG. The summary historical financial data as
of September 30, 2005 and for the nine months ended
September 30, 2005 and 2004, have been derived from the
unaudited condensed consolidated financial statements of Alpha
Natural Resources, Inc. and subsidiaries, and the related notes,
included elsewhere in this prospectus.
On October 26, 2005, we consummated the Nicewonder
Acquisition and the 2005 Financing. The aggregate purchase price
for the acquisition was $315.2 million, consisting of cash
at closing in the amount of $35.2 million, a cash tax
payment of $1.9 million to be made to the sellers in April
2006, estimated transaction costs of $3.9 million,
promissory notes payable to the sellers in the aggregate
principal amount of $221.0 million, of which
$181.1 million was paid on November 2, 2005 and
$39.9 million is due on January 15, 2006, and
2,180,233 shares of our common stock valued at
approximately $53.2 million for accounting purposes. For
this purpose, the value of the common stock issued was based on
the average closing prices of our common stock for the five
trading days surrounding October 20, 2005, the date the
number of shares to be issued under the terms of the acquisition
agreement became fixed without subsequent revision. The summary
pro forma balance sheet data as of September 30, 2005, give
pro forma effect to the Nicewonder Acquisition and the 2005
Financing, including payment of the first installment of the
notes issued to the sellers, in each case as if they had
occurred on September 30, 2005, and the summary pro forma
statement of operations data for the year ended
December 31, 2004 and the nine months ended
September 30, 2005, give pro forma effect to the 2004
Financings, the Internal Restructuring, the IPO, the Nicewonder
Acquisition and the 2005 Financing, including payment of the
first installment of the notes issued to the sellers, in each
case as if they had occurred on January 1, 2004. The
summary pro forma financial data are for informational purposes
only and should not be considered indicative of actual results
that would have been achieved had these events actually been
consummated on the dates indicated and do not purport to
indicate results of operations as of any future date or for any
future period.
The following data should be read in conjunction with
Unaudited Pro Forma Financial Information,
Selected Historical Financial Data,
Managements Discussion and Analysis of Financial
Condition and Results of Operations, and our
Predecessors and our financial statements and related
notes thereto included elsewhere in this prospectus.
9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alpha Natural Resources, Inc. and | |
|
|
|
|
ANR Fund IX Holdings, L.P. and | |
|
Subsidiaries | |
|
|
|
|
Alpha NR Holding, Inc. and Subsidiaries | |
|
| |
|
|
Predecessor | |
|
| |
|
|
|
Pro Forma | |
|
|
January 1, | |
|
December 14, | |
|
|
|
Nine Months | |
|
Pro Forma | |
|
Nine Months | |
|
Nine Months | |
|
|
2002 to | |
|
2002 to | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2004(1) | |
|
2005 | |
|
2005(1) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per share and per ton data) | |
Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
154,715 |
|
|
$ |
6,260 |
|
|
$ |
694,591 |
|
|
$ |
1,079,733 |
|
|
$ |
801,021 |
|
|
$ |
1,215,288 |
|
|
$ |
982,383 |
|
|
$ |
1,123,754 |
|
|
Freight and handling revenues
|
|
|
17,001 |
|
|
|
1,009 |
|
|
|
73,800 |
|
|
|
141,100 |
|
|
|
102,846 |
|
|
|
141,100 |
|
|
|
126,650 |
|
|
|
126,650 |
|
|
Other revenues
|
|
|
6,031 |
|
|
|
101 |
|
|
|
13,458 |
|
|
|
31,869 |
|
|
|
20,440 |
|
|
|
40,927 |
|
|
|
18,447 |
|
|
|
33,931 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
177,747 |
|
|
|
7,370 |
|
|
|
781,849 |
|
|
|
1,252,702 |
|
|
|
924,307 |
|
|
|
1,397,315 |
|
|
|
1,127,480 |
|
|
|
1,284,335 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales (exclusive of items shown separately below)
|
|
|
158,924 |
|
|
|
6,268 |
|
|
|
626,265 |
|
|
|
920,359 |
|
|
|
668,887 |
|
|
|
1,017,580 |
|
|
|
818,299 |
|
|
|
907,214 |
|
|
Freight and handling costs
|
|
|
17,001 |
|
|
|
1,009 |
|
|
|
73,800 |
|
|
|
141,100 |
|
|
|
102,846 |
|
|
|
141,100 |
|
|
|
126,650 |
|
|
|
126,650 |
|
|
Cost of other revenues
|
|
|
7,973 |
|
|
|
120 |
|
|
|
12,488 |
|
|
|
22,994 |
|
|
|
14,942 |
|
|
|
30,194 |
|
|
|
16,327 |
|
|
|
30,092 |
|
|
Depreciation, depletion and amortization
|
|
|
6,814 |
|
|
|
274 |
|
|
|
35,385 |
|
|
|
55,261 |
|
|
|
38,883 |
|
|
|
106,261 |
|
|
|
45,521 |
|
|
|
83,781 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
8,797 |
|
|
|
471 |
|
|
|
21,926 |
|
|
|
43,881 |
|
|
|
35,786 |
|
|
|
46,854 |
|
|
|
74,924 |
|
|
|
77,592 |
|
|
Costs to exit business
|
|
|
25,274 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
224,783 |
|
|
|
8,142 |
|
|
|
769,864 |
|
|
|
1,183,595 |
|
|
|
861,344 |
|
|
|
1,341,989 |
|
|
|
1,081,721 |
|
|
|
1,225,329 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refund of federal black lung excise tax
|
|
|
2,049 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other operating income, net
|
|
|
1,430 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
(43,557 |
) |
|
|
(772 |
) |
|
|
11,985 |
|
|
|
69,107 |
|
|
|
62,963 |
|
|
|
55,326 |
|
|
|
45,759 |
|
|
|
59,006 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(35 |
) |
|
|
(203 |
) |
|
|
(7,848 |
) |
|
|
(20,041 |
) |
|
|
(14,497 |
) |
|
|
(37,897 |
) |
|
|
(19,400 |
) |
|
|
(30,860 |
) |
|
Interest income
|
|
|
2,072 |
|
|
|
6 |
|
|
|
103 |
|
|
|
531 |
|
|
|
331 |
|
|
|
692 |
|
|
|
675 |
|
|
|
977 |
|
|
Miscellaneous income (expense)
|
|
|
|
|
|
|
|
|
|
|
574 |
|
|
|
722 |
|
|
|
517 |
|
|
|
444 |
|
|
|
40 |
|
|
|
132 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
2,037 |
|
|
|
(197 |
) |
|
|
(7,171 |
) |
|
|
(18,788 |
) |
|
|
(13,649 |
) |
|
|
(36,761 |
) |
|
|
(18,685 |
) |
|
|
(29,751 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations before income taxes and
minority interest
|
|
|
(41,520 |
) |
|
|
(969 |
) |
|
|
4,814 |
|
|
|
50,319 |
|
|
|
49,314 |
|
|
|
18,565 |
|
|
|
27,074 |
|
|
|
29,255 |
|
Income tax expense (benefit)
|
|
|
(17,198 |
) |
|
|
(334 |
) |
|
|
898 |
|
|
|
5,150 |
|
|
|
5,852 |
|
|
|
2,889 |
|
|
|
15,141 |
|
|
|
16,748 |
|
Minority Interest
|
|
|
|
|
|
|
|
|
|
|
1,164 |
|
|
|
22,781 |
|
|
|
22,335 |
|
|
|
|
|
|
|
2,918 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
(24,322 |
) |
|
|
(635 |
) |
|
|
2,752 |
|
|
|
22,388 |
|
|
|
21,127 |
|
|
|
15,676 |
|
|
|
9,015 |
|
|
|
12,507 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(490 |
) |
|
|
(2,373 |
) |
|
|
(2,227 |
) |
|
|
(4,054 |
) |
|
|
(214 |
) |
|
|
(267 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
(24,322 |
) |
|
$ |
(635 |
) |
|
$ |
2,262 |
|
|
$ |
20,015 |
|
|
$ |
18,900 |
|
|
$ |
11,622 |
|
|
$ |
8,801 |
|
|
$ |
12,240 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alpha Natural Resources, Inc. and | |
|
|
|
|
ANR Fund IX Holdings, L.P. and | |
|
Subsidiaries | |
|
|
|
|
Alpha NR Holding, Inc. and Subsidiaries | |
|
| |
|
|
Predecessor | |
|
| |
|
|
|
Pro Forma | |
|
|
January 1, | |
|
December 14, | |
|
|
|
Nine Months | |
|
Pro Forma | |
|
Nine Months | |
|
Nine Months | |
|
|
2002 to | |
|
2002 to | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2004(1) | |
|
2005 | |
|
2005(1) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per share and per ton data) | |
Earnings per share data(2):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
$ |
0.19 |
|
|
$ |
1.52 |
|
|
$ |
1.43 |
|
|
|
|
|
|
$ |
0.17 |
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(0.04 |
) |
|
|
(0.16 |
) |
|
|
(0.15 |
) |
|
|
|
|
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic and diluted share
|
|
|
|
|
|
|
|
|
|
$ |
0.15 |
|
|
$ |
1.36 |
|
|
$ |
1.28 |
|
|
|
|
|
|
$ |
0.16 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per basic share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
$ |
0.02 |
|
|
$ |
0.55 |
|
|
$ |
0.53 |
|
|
|
|
|
|
$ |
0.18 |
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(0.01 |
) |
|
|
(0.06 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic share
|
|
|
|
|
|
|
|
|
|
$ |
0.01 |
|
|
$ |
0.49 |
|
|
$ |
0.47 |
|
|
|
|
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per diluted share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
$ |
0.02 |
|
|
$ |
0.54 |
|
|
$ |
0.52 |
|
|
|
|
|
|
$ |
0.18 |
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(0.01 |
) |
|
|
(0.07 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per diluted share
|
|
|
|
|
|
|
|
|
|
$ |
0.01 |
|
|
$ |
0.47 |
|
|
$ |
0.46 |
|
|
|
|
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma, as adjusted, net income per basic share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.25 |
|
|
|
|
|
|
$ |
0.20 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.19 |
|
|
|
|
|
|
$ |
0.20 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma, as adjusted, net income per diluted share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.24 |
|
|
|
|
|
|
$ |
0.20 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.06 |
) |
|
|
|
|
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per diluted share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.18 |
|
|
|
|
|
|
$ |
0.19 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
11
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alpha Natural Resources, Inc. and | |
|
|
|
|
ANR Fund IX Holdings, L.P. and | |
|
Subsidiaries | |
|
|
|
|
Alpha NR Holding, Inc. and Subsidiaries | |
|
| |
|
|
Predecessor | |
|
| |
|
|
|
Pro Forma | |
|
|
January 1, | |
|
December 14, | |
|
|
|
Nine Months | |
|
Pro Forma | |
|
Nine Months | |
|
Nine Months | |
|
|
2002 to | |
|
2002 to | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2004(1) | |
|
2005 | |
|
2005(1) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per share and per ton data) | |
Balance sheet data (at period end):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
88 |
|
|
$ |
8,444 |
|
|
$ |
11,246 |
|
|
$ |
7,391 |
|
|
|
|
|
|
|
|
|
|
$ |
111 |
|
|
$ |
111 |
|
Operating and working capital
|
|
|
(4,268 |
) |
|
|
(12,223 |
) |
|
|
32,714 |
|
|
|
56,257 |
|
|
|
|
|
|
|
|
|
|
|
125,600 |
|
|
|
89,900 |
|
Total assets
|
|
|
156,328 |
|
|
|
108,442 |
|
|
|
379,336 |
|
|
|
477,121 |
|
|
|
|
|
|
|
|
|
|
|
622,098 |
|
|
|
963,209 |
|
Total debt
|
|
|
|
|
|
|
25,743 |
|
|
|
84,964 |
|
|
|
201,705 |
|
|
|
|
|
|
|
|
|
|
|
261,024 |
|
|
|
525,200 |
|
Stockholders equity and partners capital (deficit)
|
|
|
(132,997 |
) |
|
|
23,384 |
|
|
|
86,367 |
|
|
|
45,933 |
|
|
|
|
|
|
|
|
|
|
|
134,473 |
|
|
|
186,158 |
|
Statement of cash flows data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) continuing operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating activities
|
|
$ |
(13,816 |
) |
|
$ |
(295 |
) |
|
$ |
54,104 |
|
|
$ |
106,776 |
|
|
$ |
99,247 |
|
|
|
|
|
|
$ |
21,624 |
|
|
|
|
|
|
Investing activities
|
|
|
(22,054 |
) |
|
|
(38,893 |
) |
|
|
(100,072 |
) |
|
|
(86,202 |
) |
|
|
(67,235 |
) |
|
|
|
|
|
|
(93,390 |
) |
|
|
|
|
|
Financing activities
|
|
|
35,783 |
|
|
|
47,632 |
|
|
|
48,770 |
|
|
|
(24,429 |
) |
|
|
(27,447 |
) |
|
|
|
|
|
|
64,486 |
|
|
|
|
|
Capital expenditures
|
|
|
21,866 |
|
|
|
960 |
|
|
|
27,719 |
|
|
|
72,046 |
|
|
|
52,984 |
|
|
|
|
|
|
|
95,919 |
|
|
|
|
|
Other financial data (unaudited):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA(3)
|
|
$ |
(36,743 |
) |
|
$ |
(498 |
) |
|
$ |
46,729 |
|
|
$ |
99,497 |
|
|
$ |
77,150 |
|
|
$ |
156,268 |
|
|
$ |
88,378 |
|
|
$ |
142,823 |
|
Other Data (unaudited):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Tons sold
|
|
|
4,283 |
|
|
|
186 |
|
|
|
21,613 |
|
|
|
25,327 |
|
|
|
19,062 |
|
|
|
29,042 |
|
|
|
18,937 |
|
|
|
21,904 |
|
Tons produced and processed
|
|
|
4,508 |
|
|
|
87 |
|
|
|
17,199 |
|
|
|
19,068 |
|
|
|
14,518 |
|
|
|
22,904 |
|
|
|
15,062 |
|
|
|
18,003 |
|
Average coal sales realization (per ton)
|
|
$ |
36.12 |
|
|
$ |
33.66 |
|
|
$ |
32.14 |
|
|
$ |
42.63 |
|
|
$ |
42.02 |
|
|
$ |
41.85 |
|
|
$ |
51.88 |
|
|
$ |
51.30 |
|
|
|
(1) |
The unaudited pro forma statement of operations data give pro
forma effect to the 2004 Financings, Internal Restructuring,
IPO, Nicewonder Acquisition, and 2005 Financing, including
payment of the first installment on the notes issued to the
Nicewonder Coal Group sellers, as if they had occurred on
January 1, 2004. |
|
(2) |
Basic earnings per share is computed by dividing net income or
loss by the weighted average number of shares of common stock
outstanding during the periods. Diluted earnings per share is
computed by dividing net income or loss by the weighted average
number of shares of common stock and dilutive common stock
equivalents outstanding during the periods. Common stock
equivalents include the number of shares issuable on exercise of
outstanding options less the number of shares that could have
been purchased with the proceeds from the exercise of the
options based on the average price of common stock during the
period. |
|
|
|
We have disclosed for informational purposes three sets of
earnings per share data: |
|
|
Net Income (Loss) Per Share, as Adjusted |
|
|
The first set of earnings per share data is labeled net
income (loss) per share, as adjusted. The numerator for
purposes of computing basic and diluted net income (loss) per
share, as adjusted, includes the reported net income (loss) and
a pro forma adjustment for income taxes to reflect the pro forma
income taxes for ANR Fund IX Holdings, L.P.s portion
of reported pre-tax income (loss), which would have been
recorded if the issuance of the shares of common stock received
by the First Reserve Stockholders in exchange for their
ownership in ANR Holdings in connection with the Internal
Restructuring had occurred as of January 1, 2003. For
purposes of the computation of basic and diluted net income
(loss) per share, as adjusted, the pro forma adjustment for
income taxes only applies to the percentage interest owned by
ANR Fund IX Holding, L.P., the non-taxable First Reserve
Stockholder. No pro forma adjustment for income taxes is
required for the percentage interest owned by Alpha NR Holding,
Inc., the taxable First Reserve Stockholder, because income
taxes have already been recorded in the historical results of
operations. Furthermore, no pro forma adjustment to reported net
income (loss) is necessary subsequent to February 11, 2005
because Alpha Natural Resources, Inc. is subject to income taxes. |
12
|
|
|
The denominator for purposes of computing basic net income
(loss) per share, as adjusted, reflects the retroactive impact
of the common shares received by the First Reserve Stockholders
in exchange for their ownership in ANR Holdings in connection
with the Internal Restructuring on a weighted-average
outstanding share basis as being outstanding as of
January 1, 2003. The common shares issued to the minority
interest owners of ANR Holdings in connection with the Internal
Restructuring, including the immediately vested shares granted
to management, have been reflected as being outstanding as of
February 11, 2005 for purposes of computing the basic net
income (loss) per share, as adjusted. The unvested shares
granted to management on February 11, 2005 that vest
monthly over the two-year period from January 1, 2005 to
December 31, 2006 are included in the basic net income
(loss) per share, as adjusted, computation as they vest on a
weighted-average outstanding share basis starting on
February 11, 2005. The 33,925,000 new shares issued in
connection with the IPO have been reflected as being outstanding
since February 14, 2005, the date of the IPO, for purposes
of computing the basic net income (loss) per share, as adjusted. |
|
|
The unvested shares issued to management are considered options
for purposes of computing diluted net income (loss) per share,
as adjusted. Therefore, for diluted purposes, all remaining
unvested shares granted to management are added to the
denominator subsequent to February 11, 2005 using the
treasury stock method, if the effect is dilutive. In addition,
the treasury stock method is used for outstanding stock options,
if dilutive, beginning with the November 10, 2004 grant of
options to management to purchase units in Alpha Coal Management
that were automatically converted into options to purchase up to
596,985 shares of our common stock at an exercise price of
$12.73 per share. |
|
|
The computations of basic and diluted net income (loss) per
share, as adjusted, are set forth below: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
Years Ended December 31, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share and per share data) | |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported income from continuing operations
|
|
$ |
2,752 |
|
|
$ |
22,388 |
|
|
$ |
21,127 |
|
|
$ |
9,015 |
|
|
Deduct: Income tax effect of ANR Fund IX Holdings, L.P.
income from continuing operations prior to Internal Restructuring
|
|
|
(138 |
) |
|
|
(1,149 |
) |
|
|
(1,124 |
) |
|
|
(91 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
|
2,614 |
|
|
|
21,239 |
|
|
|
20,003 |
|
|
|
8,924 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported loss from discontinued operations
|
|
$ |
(490 |
) |
|
$ |
(2,373 |
) |
|
$ |
(2,227 |
) |
|
$ |
(214 |
) |
|
Add: Income tax effect of ANR Fund IX Holdings, L.P. income
from discontinued operations prior to Internal Restructuring
|
|
|
27 |
|
|
|
149 |
|
|
|
139 |
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations, as adjusted
|
|
|
(463 |
) |
|
|
(2,224 |
) |
|
|
(2,088 |
) |
|
|
(212 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income, as adjusted
|
|
$ |
2,151 |
|
|
$ |
19,015 |
|
|
$ |
17,915 |
|
|
$ |
8,712 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares basic
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
53,184,066 |
|
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
382,403 |
|
|
|
|
Weighted average shares diluted
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
53,566,469 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic and diluted share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.19 |
|
|
$ |
1.52 |
|
|
$ |
1.43 |
|
|
$ |
0.17 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.04 |
) |
|
|
(0.16 |
) |
|
|
(0.15 |
) |
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.15 |
|
|
$ |
1.36 |
|
|
$ |
1.28 |
|
|
$ |
0.16 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro Forma Net Income (Loss) Per Share |
|
|
The second set of earnings per share data is labeled pro
forma net income (loss) per share. The numerator for
purposes of computing basic and diluted pro forma net income
(loss) per share is based on net income, as adjusted
(as calculated above) and pro forma adjustments to reflect the
impact of: |
|
|
|
|
(i) |
the add back of minority interest for each period presented,
because the ownership held by the minority interest owners of
ANR Holdings were exchanged for shares of our common stock as
part of the Internal Restructuring; |
|
|
(ii) |
the additional income taxes that would have been incurred by us
on the minority interest added back; and |
|
|
(iii) |
the issuance of $175,000 principal amount of 10% senior
notes due 2012 by our subsidiaries Alpha Natural Resources, LLC
and Alpha Natural Resources Capital Corp. and the entry by Alpha
Natural Resources, LLC into a $175,000 credit facility in May
2004, in connection with the 2004 Financings, as if these
transactions had occurred on January 1, 2003. |
|
|
|
No pro forma adjustment to reported net income (loss) is
necessary subsequent to February 11, 2005. |
13
|
|
|
The denominator for purposes of computing basic pro forma net
income (loss) per share reflects: |
|
|
|
|
(i) |
the retroactive impact of the common shares received by the
First Reserve Stockholders in exchange for their ownership in
ANR Holdings in connection with the Internal Restructuring on a
weighted-average outstanding share basis as being outstanding as
of January 1, 2003; |
|
|
(ii) |
the retroactive impact of the common shares issued to the
minority interest owners of ANR Holdings in connection with the
Internal Restructuring, including the immediately vested shares
granted to management, on a weighted-average outstanding share
basis as being outstanding as of January 1, 2003; |
|
|
(iii) |
the unvested shares granted to management that vest over the
two-year period from January 1, 2005 to December 31,
2006, which have been included in the basic computation on a
weighted-average outstanding share basis based on the monthly
vesting beginning as of January 1, 2005; and |
|
|
(iv) |
the retroactive impact of the 33,925,000 new shares issued in
connection with the IPO on a weighted-average outstanding share
basis as being outstanding as of January 1, 2003 since 100%
of the net proceeds from the IPO was distributed to the previous
owners of ANR Holdings. |
|
|
|
The unvested shares issued to management are considered options
for purposes of computing diluted pro forma net income (loss)
per share. Therefore, for diluted purposes, all remaining
unvested shares granted to management would be added to the
denominator as of January 1, 2003 using the treasury stock
method, if the effect is dilutive. In addition, the treasury
stock method would be used for outstanding stock options, if
dilutive, beginning with the November 10, 2004 grant of
options to management to purchase units in Alpha Coal Management
that were automatically converted into options to purchase up to
596,985 shares of our common stock at an exercise price of
$12.73 per share. |
|
|
The computations of basic and diluted pro forma net income
(loss) per share, are set forth below: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
Years Ended December 31, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share and per share data) | |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
$ |
2,614 |
|
|
$ |
21,239 |
|
|
$ |
20,003 |
|
|
$ |
8,924 |
|
|
Add: Minority interest in income from continuing operations, net
of income tax effect
|
|
|
2,822 |
|
|
|
14,124 |
|
|
|
13,848 |
|
|
|
2,231 |
|
|
Add: Pro forma effects related to the 2003 Acquisitions, net of
income taxes(1)
|
|
|
3,507 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deduct: Pro forma effects of the 2004 Financings, net of income
taxes
|
|
|
(7,728 |
) |
|
|
(1,672 |
) |
|
|
(1,614 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
|
1,215 |
|
|
|
33,691 |
|
|
|
32,237 |
|
|
|
11,155 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations, as adjusted
|
|
$ |
(463 |
) |
|
$ |
(2,224 |
) |
|
$ |
(2,088 |
) |
|
$ |
(212 |
) |
|
Add: Minority interest in income (loss) from discontinued
operations, net of income tax effect
|
|
|
(216 |
) |
|
|
(1,830 |
) |
|
|
(1,719 |
) |
|
|
(55 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma loss from discontinued operations
|
|
|
(679 |
) |
|
|
(4,054 |
) |
|
|
(3,807 |
) |
|
|
(267 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
$ |
536 |
|
|
$ |
29,637 |
|
|
$ |
28,430 |
|
|
$ |
10,888 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares basic
|
|
|
60,867,650 |
|
|
|
60,867,650 |
|
|
|
60,867,650 |
|
|
|
61,092,832 |
|
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
1,541,936 |
|
|
|
1,541,936 |
|
|
|
379,183 |
|
|
|
584,389 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares diluted
|
|
|
62,409,586 |
|
|
|
62,409,586 |
|
|
|
61,246,833 |
|
|
|
61,677,221 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per basic share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.02 |
|
|
$ |
0.55 |
|
|
$ |
0.53 |
|
|
$ |
0.18 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.01 |
) |
|
|
(0.06 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.01 |
|
|
$ |
0.49 |
|
|
$ |
0.47 |
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per diluted share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.02 |
|
|
$ |
0.54 |
|
|
$ |
0.52 |
|
|
$ |
0.18 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.01 |
) |
|
|
(0.07 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.01 |
|
|
$ |
0.47 |
|
|
$ |
0.46 |
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
See Managements Discussion and Analysis of Financial
Condition and Results of Operations
Overview Predecessor and 2003 Acquisitions for
a definition and explanation of the 2003
Acquisitions. |
14
|
|
|
Pro Forma Net Income (Loss) Per Share, As Adjusted |
|
|
The third set of earnings per share data is labeled pro
forma net income (loss) per share, as adjusted. The
numerator for purposes of computing basic and diluted pro forma
net income (loss) per share, as adjusted, is based on pro
forma net income (loss) (as calculated above) and pro
forma adjustments to reflect the impact of the Nicewonder
Acquisition and the 2005 Financing, as if these transactions had
occurred on January 1, 2004. |
|
|
The denominator for purposes of computing pro forma net income
(loss) per share, as adjusted, is based on the weighted average
shares outstanding for purposes of net income (loss) per
share, as adjusted (as calculated above) plus
2.2 million shares to be issued in connection with the
Nicewonder Acquisition, assuming such issuance had occurred on
January 1, 2004. |
|
|
The computations of basic and diluted pro forma net income
(loss) per share, as adjusted, are set forth below: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended | |
|
Nine Months Ended | |
|
|
December 31, 2004 | |
|
September 30, 2005 | |
|
|
| |
|
| |
Numerator:
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
$ |
33,691 |
|
|
$ |
11,155 |
|
|
Add: Pro forma income (loss) related to the Nicewonder
Acquisition, net of income taxes
|
|
|
(9,454 |
) |
|
|
7,470 |
|
|
Deduct: Pro forma effects of the 2005 Financing, net of income
taxes
|
|
|
(8,561 |
) |
|
|
(6,118 |
) |
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations, as adjusted
|
|
|
15,676 |
|
|
|
12,507 |
|
|
|
|
|
|
|
|
|
Pro forma loss from discontinued operations
|
|
$ |
(4,054 |
) |
|
$ |
(267 |
) |
|
Adjustments
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma loss from discontinued operations, as adjusted
|
|
|
(4,054 |
) |
|
|
(267 |
) |
|
|
|
|
|
|
|
|
Pro forma net income, as adjusted
|
|
$ |
11,769 |
|
|
$ |
12,240 |
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares basic
|
|
|
63,047,883 |
|
|
|
63,273,065 |
|
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
1,541,936 |
|
|
|
584,389 |
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares diluted
|
|
|
64,589,819 |
|
|
|
63,857,454 |
|
|
|
|
|
|
|
|
Pro forma net income per basic share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.25 |
|
|
$ |
0.20 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.19 |
|
|
$ |
0.20 |
|
|
|
|
|
|
|
|
Pro forma net income per diluted share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.24 |
|
|
$ |
0.20 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.06 |
) |
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.18 |
|
|
$ |
0.19 |
|
|
|
|
|
|
|
|
|
|
(3) |
EBITDA, a measure used by management to measure operating
performance, is defined as net income (loss) plus interest
expense, income tax expense (benefit) and depreciation,
depletion, and amortization, less interest income. We have
presented EBITDA because our management believes that it is
frequently used by securities analysts, investors, and other
interested parties in the evaluation of coal companies. We
regularly evaluate our performance as compared to other coal
companies that have different financing and capital structures
and/or tax rates by using EBITDA. We believe that EBITDA allows
for meaningful company-to-company performance comparisons by
adjusting for factors such as interest expense, depreciation,
depletion, amortization and taxes, which can vary from company
to company. In addition, we use EBITDA in evaluating acquisition
targets. EBITDA is not a recognized term under GAAP and does not
purport to be an alternative to net income, operating income or
any other performance measures derived in accordance with GAAP
or an alternative to cash flow from operating activities as a
measure of operating liquidity. Because not all companies use
identical calculations, this presentation of EBITDA may not be
comparable to other similarly titled measures of other
companies. Additionally, EBITDA is not intended to be a measure
of free cash flow for managements discretionary use, as it
does not reflect certain cash requirements such as tax payments,
interest payments and other debt service requirements. The
amounts presented for EBITDA differ from the amounts calculated
under the definition of EBITDA used in our debt covenants. The
definition of EBITDA used in our debt covenants is further
adjusted for certain cash and non-cash charges and is used to
determine compliance with financial covenants and our ability to
engage in certain activities such as incurring debt and making
certain payments. Adjusted EBITDA as it is used and defined in
our debt covenants is described and reconciled to net income
(loss) in Managements Discussion and Analysis of
Financial Condition and Results of Operations
Analysis of Material Debt Covenants. |
15
|
|
|
EBITDA is calculated and reconciled to net income (loss) in the
table below: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alpha Natural Resources, Inc. and | |
|
|
|
|
ANR Fund IX Holdings, L.P. and | |
|
Subsidiaries | |
|
|
|
|
Alpha NR Holding, Inc. and Subsidiaries | |
|
| |
|
|
|
|
| |
|
|
|
Pro Forma | |
|
|
January 1, | |
|
December 14, | |
|
|
|
Nine Months | |
|
Pro Forma | |
|
Nine Months | |
|
Nine Months | |
|
|
2002 to | |
|
2002 to | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands) | |
Net income (loss)
|
|
$ |
(24,322 |
) |
|
$ |
(635 |
) |
|
$ |
2,262 |
|
|
$ |
20,015 |
|
|
$ |
18,900 |
|
|
$ |
11,622 |
|
|
$ |
8,801 |
|
|
$ |
12,240 |
|
Interest expense
|
|
|
35 |
|
|
|
203 |
|
|
|
7,848 |
|
|
|
20,041 |
|
|
|
14,497 |
|
|
|
37,897 |
|
|
|
19,400 |
|
|
|
30,860 |
|
Interest income
|
|
|
(2,072 |
) |
|
|
(6 |
) |
|
|
(103 |
) |
|
|
(531 |
) |
|
|
(331 |
) |
|
|
(692 |
) |
|
|
(675 |
) |
|
|
(977 |
) |
Income tax expense (benefit)(a)
|
|
|
(17,198 |
) |
|
|
(334 |
) |
|
|
668 |
|
|
|
3,960 |
|
|
|
4,732 |
|
|
|
429 |
|
|
|
15,048 |
|
|
|
16,636 |
|
Depreciation, depletion and amortization(b)
|
|
|
6,814 |
|
|
|
274 |
|
|
|
36,054 |
|
|
|
56,012 |
|
|
|
39,352 |
|
|
|
107,012 |
|
|
|
45,804 |
|
|
|
84,064 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$ |
(36,743 |
) |
|
$ |
(498 |
) |
|
$ |
46,729 |
|
|
$ |
99,497 |
|
|
$ |
77,150 |
|
|
$ |
156,268 |
|
|
$ |
88,378 |
|
|
$ |
142,823 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) |
Includes income tax expense (benefit) from continuing and
discontinued operations. |
(b) |
Includes depreciation, depletion and amortization from
continuing and discontinued operations. |
16
Nicewonder Summary Historical Financial Data
The following summary historical financial data of the
Nicewonder Coal Group as of December 31, 2004, 2003 and
2002 and for the years ended December 31, 2004, 2003 and
2002, have been derived from the combined financial statements
of the Nicewonder Coal Group, and the related notes, included
elsewhere in this prospectus, which have been audited by KPMG
LLP, independent accountants. The summary historical financial
data as of September 30, 2005 and for the nine months ended
September 30, 2004 and 2005, have been derived from the
unaudited combined financial statements of the Nicewonder Coal
Group, and the related notes, included elsewhere in this
prospectus.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Combined Entities of The Nicewonder Coal Group | |
|
|
| |
|
|
|
|
Nine Months | |
|
Nine Months | |
|
|
Year Ended | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per ton data) | |
Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
96,793 |
|
|
$ |
103,600 |
|
|
$ |
135,555 |
|
|
$ |
101,663 |
|
|
$ |
141,371 |
|
|
Other revenues
|
|
|
1,744 |
|
|
|
2,128 |
|
|
|
9,058 |
|
|
|
4,533 |
|
|
|
15,484 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
98,537 |
|
|
|
105,728 |
|
|
|
144,613 |
|
|
|
106,196 |
|
|
|
156,855 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales (exclusive of items shown separately below)
|
|
|
79,713 |
|
|
|
83,818 |
|
|
|
96,758 |
|
|
|
72,402 |
|
|
|
88,568 |
|
|
Cost of other revenues
|
|
|
1,490 |
|
|
|
1,419 |
|
|
|
7,200 |
|
|
|
3,204 |
|
|
|
13,765 |
|
|
Depreciation, depletion and amortization
|
|
|
10,812 |
|
|
|
11,855 |
|
|
|
11,336 |
|
|
|
8,508 |
|
|
|
10,340 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
2,458 |
|
|
|
2,310 |
|
|
|
2,973 |
|
|
|
2,402 |
|
|
|
2,668 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
94,473 |
|
|
|
99,402 |
|
|
|
118,267 |
|
|
|
86,516 |
|
|
|
115,341 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
4,064 |
|
|
|
6,326 |
|
|
|
26,346 |
|
|
|
19,680 |
|
|
|
41,514 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,798 |
) |
|
|
(1,487 |
) |
|
|
(1,351 |
) |
|
|
(964 |
) |
|
|
(1,593 |
) |
|
Interest income
|
|
|
545 |
|
|
|
246 |
|
|
|
161 |
|
|
|
66 |
|
|
|
302 |
|
|
Net realized gain on sale of marketable securities
|
|
|
971 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Miscellaneous income (loss)
|
|
|
74 |
|
|
|
(15 |
) |
|
|
(278 |
) |
|
|
(42 |
) |
|
|
92 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(208 |
) |
|
|
(1,256 |
) |
|
|
(1,468 |
) |
|
|
(940 |
) |
|
|
(1,199 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before cumulative effect of accounting change
|
|
|
3,856 |
|
|
|
5,070 |
|
|
|
24,878 |
|
|
|
18,740 |
|
|
|
40,315 |
|
Cumulative effect of accounting change
|
|
|
|
|
|
|
(460 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
3,856 |
|
|
$ |
4,610 |
|
|
$ |
24,878 |
|
|
$ |
18,740 |
|
|
$ |
40,315 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Combined Entities of The Nicewonder Coal Group | |
|
|
| |
|
|
|
|
Nine Months | |
|
Nine Months | |
|
|
Year Ended | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per ton data) | |
Balance sheet data (at period end): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
3,823 |
|
|
$ |
1,787 |
|
|
$ |
12,707 |
|
|
|
|
|
|
$ |
22,998 |
|
Operating and working capital
|
|
|
(4,551 |
) |
|
|
(5,491 |
) |
|
|
7,956 |
|
|
|
|
|
|
|
16,169 |
|
Total assets
|
|
|
74,620 |
|
|
|
70,701 |
|
|
|
105,557 |
|
|
|
|
|
|
|
130,796 |
|
Notes payable and long-term debt, including current portion
|
|
|
30,462 |
|
|
|
23,438 |
|
|
|
34,729 |
|
|
|
|
|
|
|
43,870 |
|
Stockholders equity and members equity
|
|
|
33,998 |
|
|
|
31,779 |
|
|
|
49,293 |
|
|
|
|
|
|
|
62,449 |
|
Statement of cash flows data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating activities
|
|
$ |
15,857 |
|
|
$ |
17,802 |
|
|
$ |
36,963 |
|
|
$ |
28,072 |
|
|
$ |
51,269 |
|
|
Investing activities
|
|
|
(2,245 |
) |
|
|
(463 |
) |
|
|
(1,639 |
) |
|
|
(922 |
) |
|
|
(2,636 |
) |
|
Financing activities
|
|
|
(14,392 |
) |
|
|
(19,375 |
) |
|
|
(24,403 |
) |
|
|
(18,452 |
) |
|
|
(38,342 |
) |
Capital expenditures
|
|
|
3,436 |
|
|
|
2,723 |
|
|
|
1,704 |
|
|
|
845 |
|
|
|
3,101 |
|
Other financial data (Unaudited):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA(1)
|
|
$ |
15,921 |
|
|
$ |
17,706 |
|
|
$ |
37,404 |
|
|
$ |
28,146 |
|
|
$ |
51,946 |
|
Other data (Unaudited):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Tons sold
|
|
|
3,255 |
|
|
|
3,406 |
|
|
|
3,715 |
|
|
|
2,862 |
|
|
|
2,967 |
|
|
Tons produced and processed
|
|
|
3,292 |
|
|
|
3,374 |
|
|
|
3,836 |
|
|
|
3,024 |
|
|
|
2,941 |
|
|
Average coal sales realization (per ton)
|
|
$ |
29.74 |
|
|
$ |
30.42 |
|
|
$ |
36.49 |
|
|
$ |
35.52 |
|
|
$ |
47.65 |
|
|
|
(1) |
EBITDA, a measure used by management to measure operating
performance, is defined as net income (loss) plus interest
expense, income tax expense (benefit) and depreciation,
depletion, and amortization, less interest income. We have
presented EBITDA because our management believes that it is
frequently used by securities analysts, investors, and other
interested parties in the evaluation of coal companies. We
regularly evaluate our performance as compared to other coal
companies that have different financing and capital structures
and/or tax rates by using EBITDA. We believe that EBITDA allows
for meaningful company-to-company performance comparisons by
adjusting for factors such as interest expense, depreciation,
depletion, amortization and taxes, which can vary from company
to company. In addition, we use EBITDA in evaluating acquisition
targets. EBITDA is not a recognized term under GAAP and does not
purport to be an alternative to net income, operating income or
any other performance measures derived in accordance with GAAP
or an alternative to cash flow from operating activities as a
measure of operating liquidity. Because not all companies use
identical calculations, this presentation of EBITDA may not be
comparable to other similarly titled measures of other
companies. Additionally, EBITDA is not intended to be a measure
of free cash flow for managements discretionary use, as it
does not reflect certain cash requirements such as tax payments,
interest payments and other debt service requirements. |
18
EBITDA is calculated and reconciled to net income in the table
below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Combined Entities of The Nicewonder Coal Group | |
|
|
| |
|
|
|
|
Nine Months | |
|
Nine Months | |
|
|
Year Ended | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands) | |
Net income
|
|
$ |
3,856 |
|
|
$ |
4,610 |
|
|
$ |
24,878 |
|
|
$ |
18,740 |
|
|
$ |
40,315 |
|
Interest expense
|
|
|
1,798 |
|
|
|
1,487 |
|
|
|
1,351 |
|
|
|
964 |
|
|
|
1,593 |
|
Interest income
|
|
|
(545 |
) |
|
|
(246 |
) |
|
|
(161 |
) |
|
|
(66 |
) |
|
|
(302 |
) |
Depreciation, depletion and amortization
|
|
|
10,812 |
|
|
|
11,855 |
|
|
|
11,336 |
|
|
|
8,508 |
|
|
|
10,340 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$ |
15,921 |
|
|
$ |
17,706 |
|
|
$ |
37,404 |
|
|
$ |
28,146 |
|
|
$ |
51,946 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
19
RISK FACTORS
Investing in our common stock involves risks. You should
carefully consider the risks described below as well as the
other information contained in this prospectus before investing
in our common stock.
Risks Relating to Our Business
|
|
|
A substantial or extended decline in coal prices could
reduce our revenues and the value of our coal reserves. |
Our results of operations are substantially dependent upon the
prices we receive for our coal. The prices we receive for coal
depend upon factors beyond our control, including:
|
|
|
|
|
the supply of and demand for domestic and foreign coal; |
|
|
|
the demand for electricity; |
|
|
|
domestic and foreign demand for steel and the continued
financial viability of the domestic and/or foreign steel
industry; |
|
|
|
the proximity to, capacity of, and cost of transportation
facilities; |
|
|
|
domestic and foreign governmental regulations and taxes; |
|
|
|
air emission standards for coal-fired power plants; |
|
|
|
regulatory, administrative, and judicial decisions; |
|
|
|
the price and availability of alternative fuels, including the
effects of technological developments; and |
|
|
|
the effect of worldwide energy conservation measures. |
Declines in the prices we receive for our coal could adversely
affect our operating results and our ability to generate the
cash flows we require to improve our productivity and invest in
our operations.
|
|
|
Our coal mining production and delivery is subject to
conditions and events beyond our control, which could result in
higher operating expenses and/or decreased production and sales
and adversely affect our operating results. |
Our coal mining operations are conducted, in large part, in
underground mines and, to a lesser extent, at surface mines. The
level of our production at these mines is subject to operating
conditions and events beyond our control that could disrupt
operations, affect production and the cost of mining at
particular mines for varying lengths of time and have a
significant impact on our operating results. Adverse operating
conditions and events that we or our Predecessor have
experienced in the past include:
|
|
|
|
|
delays and difficulties in acquiring, maintaining or renewing
necessary permits or mining or surface rights; |
|
|
|
changes or variations in geologic conditions, such as the
thickness of the coal deposits and the amount of rock embedded
in or overlying the coal deposit; |
|
|
|
mining and processing equipment failures and unexpected
maintenance problems; |
|
|
|
limited availability of mining and processing equipment and
parts from suppliers; |
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interruptions due to transportation delays; |
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adverse weather and natural disasters, such as heavy rains and
flooding; |
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accidental mine water discharges; |
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the termination of material contracts by state or other
governmental authorities; |
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the unavailability of qualified labor; |
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strikes and other labor-related interruptions; and |
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unexpected mine safety accidents, including fires and explosions
from methane and other sources. |
If any of these conditions or events occur in the future at any
of our mines or affect deliveries of our coal to customers, they
may increase our cost of mining and delay or halt production at
particular mines or sales to our customers either permanently or
for varying lengths of time, which could adversely affect our
operating results. For example, in 2004 we experienced mine roof
stability issues at our Kingwood underground mine, which
resulted in a 23% decrease in production at this mine for 2004
as compared to 2003 full-year production (including production
in 2003 prior to our acquisition of the mine). In addition,
Hurricanes Katrina and Rita, which struck the Gulf Coast in
August and September 2005, resulted in delayed shipments of our
coal to our customers, and Hurricane Katrina also damaged a
portion of 330,000 tons of metallurgical coal inventory that we
had stockpiled in New Orleans to meet 2005 sales commitments. We
recorded a pre-tax charge of $0.7 million in the third
quarter of 2005 for such inventory loss, representing the
estimated total loss in the amount of $1.2 million, less
the portion of the loss expected to be recovered by insurance
claims of $0.5 million. The actual amount of the inventory
loss and the insurance recovery may be different than our
estimates. We expect to determine the final amounts of the
inventory loss and insurance recovery during the process of
preparing our financial statements for the fourth quarter of
2005.
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Any change in coal consumption patterns by steel producers
or North American electric power generators resulting in a
decrease in the use of coal by those consumers could result in
lower prices for our coal, which would reduce our revenues and
adversely impact our earnings and the value of our coal
reserves. |
Steam coal accounted for approximately 62% of our coal sales
volume during the first nine months of 2005 and approximately
63% of our 2004 coal sales volume. The majority of our sales of
steam coal for the first nine months of 2005 and for 2004 was to
U.S. and Canadian electric power generators. Domestic electric
power generation accounted for approximately 92% of all
U.S. coal consumption in 2004, according to the EIA. The
amount of coal consumed for U.S. and Canadian electric power
generation is affected primarily by the overall demand for
electricity, the location, availability, quality and price of
competing fuels for power such as natural gas, nuclear, fuel oil
and alternative energy sources such as hydroelectric power,
technological developments, and environmental and other
governmental regulations. We expect many new power plants will
be built to produce electricity during peak periods of demand,
when the demand for electricity rises above the base load
demand, or minimum amount of electricity required if
consumption occurred at a steady rate. However, we also expect
that many of these new power plants will be fired by natural gas
because they are cheaper to construct than coal-fired plants and
because natural gas is a cleaner burning fuel. In addition, the
increasingly stringent requirements of the Clean Air Act may
result in more electric power generators shifting from coal to
natural gas-fired power plants. Any reduction in the amount of
coal consumed by North American electric power generators could
reduce the price of steam coal that we mine and sell, thereby
reducing our revenues and adversely impacting our earnings and
the value of our coal reserves.
We produce metallurgical coal that is used in both the U.S. and
foreign steel industries. Metallurgical coal accounted for
approximately 38% of our coal sales volume during the first nine
months of 2005 and approximately 37% of our 2004 coal sales
volume. In recent years, U.S. steel producers have
experienced a substantial decline in the prices received for
their products, due at least in part to a heavy volume of
foreign steel imported into the United States. Although prices
for some U.S. steel products increased moderately after the
Bush administration imposed steel import tariffs and quotas in
March 2002, those tariffs and quotas were lifted in December
2003. Furthermore, recent reports by the American Iron and Steel
Institute indicate that the volume of shipments by
U.S. steel mills in September 2005 was down 3.4% from the
previous month and 6.5% from September 2004 and that, based on
preliminary data for October 2005, U.S. steel imports for
October 2005 and the ten months ended October 31, 2005 were
approximately 28% and 10% lower, respectively, than in the
applicable prior year periods, which may be
21
leading indicators of declining demand in the U.S. steel
industry generally. Any deterioration in conditions in the
U.S. steel industry would reduce the demand for our
metallurgical coal and impact the collectibility of our accounts
receivable from U.S. steel industry customers. In addition,
the U.S. steel industry increasingly relies on electric arc
furnaces or pulverized coal processes to make steel. These
processes do not use coke. If this trend continues, the amount
of metallurgical coal that we sell and the prices that we
receive for it could decrease, thereby reducing our revenues and
adversely impacting our earnings and the value of our coal
reserves. In the international market for metallurgical coal,
there are indications that coal prices may have begun to level
off or decline from their current, historically high levels. In
a report issued at the end of November, the EIA reported that
2005 steel production in China has been well above projections,
resulting in a glut of steel despite Chinas current
position as the worlds largest consumer of steel. Despite
the restrictions on metallurgical coal exports announced by
China in 2003, the EIA noted reports of Chinese producers
offering coke for export at Chinese ports. If the demand and
pricing for metallurgical coal in international markets
decreases in the future, the amount of metallurgical coal that
we sell and the prices that we receive for it could decrease,
thereby reducing our revenues and adversely impacting our
earnings and the value of our coal reserves.
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A decline in demand for metallurgical coal would limit our
ability to sell our high quality steam coal as higher-priced
metallurgical coal and could affect the economic viability of
certain of our mines that have higher operating costs. |
Portions of our coal reserves possess quality characteristics
that enable us to mine, process and market them as either
metallurgical coal or high quality steam coal, depending on the
prevailing conditions in the metallurgical and steam coal
markets. We decide whether to mine, process and market these
coals as metallurgical or steam coal based on managements
assessment as to which market is likely to provide us with a
higher margin. We consider a number of factors when making this
assessment, including the difference between the current and
anticipated future market prices of steam coal and metallurgical
coal, the lower volume of saleable tons that results from
producing a given quantity of reserves for sale in the
metallurgical market instead of the steam market, the increased
costs incurred in producing coal for sale in the metallurgical
market instead of the steam market, the likelihood of being able
to secure a longer-term sales commitment by selling coal into
the steam market and our contractual commitments to deliver
different types of coals to our customers. During 2004, we
believe that we sold approximately 8% of our produced and
processed coal as metallurgical coal that we would have sold as
steam coal in the market conditions prevalent during 2003. We
believe that we generated approximately $65.0 million in
additional revenues by selling this production as metallurgical
coal rather than steam coal during 2004, based on a comparison
of the actual sales price and volume versus the then-prevailing
market price for steam coal and the volume of coal that we would
have sold if the coal had been mined, processed and marketed as
steam coal. A decline in the metallurgical market relative to
the steam market could cause us to shift coal from the
metallurgical market to the steam market, thereby reducing our
revenues and profitability.
Most of our metallurgical coal reserves possess quality
characteristics that enable us to mine, process and market them
as high quality steam coal. However, some of our mines operate
profitably only if all or a portion of their production is sold
as metallurgical coal to the steel market. If demand for
metallurgical coal declined to the point where we could earn a
more attractive return marketing the coal as steam coal, these
mines may not be economically viable and may be subject to
closure. Such closures would lead to accelerated reclamation
costs, as well as reduced revenue and profitability.
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Acquisitions that we have completed since our formation,
as well as acquisitions that we may undertake in the future,
involve a number of risks, any of which could cause us not to
realize the anticipated benefits. |
Since our formation and the acquisition of our Predecessor in
December 2002, we have completed four significant acquisitions
and several smaller acquisitions and investments. We continually
seek to expand our operations and coal reserves through
acquisitions. If we are unable to successfully integrate the
companies, businesses or properties we are able to acquire, our
profitability may decline and we could experience a material
adverse effect on our business, financial condition, or results
of operations. Acquisition transactions involve various inherent
risks, including:
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uncertainties in assessing the value, strengths, and potential
profitability of, and identifying the extent of all weaknesses,
risks, contingent and other liabilities (including environmental
or mine safety liabilities) of, acquisition candidates; |
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the potential loss of key customers, management and employees of
an acquired business; |
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the ability to achieve identified operating and financial
synergies anticipated to result from an acquisition; |
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problems that could arise from the integration of the acquired
business; and |
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unanticipated changes in business, industry or general economic
conditions that affect the assumptions underlying our rationale
for pursuing the acquisition. |
Any one or more of these factors could cause us not to realize
the benefits anticipated to result from an acquisition. For
example, in combining our Predecessor and acquired companies, we
have incurred significant expenses to develop unified reporting
systems and standardize our accounting functions. Additionally,
we were unable to profitably operate NKC, which we acquired in
connection with our acquisition of AMCI. In September 2004, we
recorded an impairment charge of $5.1 million to reduce the
carrying value of the assets of NKC to their estimated fair
value, and we sold the assets of NKC on April 14, 2005.
The recently completed Nicewonder Acquisition has increased the
size of our operations. Our ability to integrate the operations
of the Nicewonder Coal Group with our own is important to our
future success. If we are unable to realize the anticipated
benefits of the Nicewonder Acquisition due to our inability to
address the challenges of integrating the Nicewonder Coal Group
or for any other reason, it could have a material adverse effect
on our business and financial and operating results and require
significant additional time on the part of our senior management
dedicated to resolving integration issues.
Moreover, any acquisition opportunities we pursue could
materially affect our liquidity and capital resources and may
require us to incur indebtedness, seek equity capital or both.
For instance, in connection with the Nicewonder Acquisition, we
issued $221.0 million principal amount of promissory
installment notes of one of our indirect, wholly owned
subsidiaries, we issued 2,180,233 shares of our common stock
valued at approximately $53.2 million, and we entered into
a new $525.0 million credit facility, a portion of the net
proceeds of which we used to pay the cash purchase price,
acquisition expenses and the first installment of principal due
on the promissory notes. In addition, future acquisitions could
result in our assuming more long-term liabilities relative to
the value of the acquired assets than we have assumed in our
previous acquisitions.
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The inability of the sellers of our Predecessor and
acquired companies to fulfill their indemnification obligations
to us under our acquisition agreements could increase our
liabilities and adversely affect our results of operations and
financial position. |
In the acquisition agreements we entered into with the sellers
of our Predecessor and acquired companies, including the
acquisition agreements we entered into related to the Nicewonder
Acquisition, the respective sellers and, in some of our
acquisitions, their parent companies, agreed to retain
responsibility for and indemnify us against damages resulting
from certain third-party claims or other
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liabilities, such as workers compensation liabilities,
black lung liabilities, postretirement medical liabilities and
certain environmental or mine safety liabilities. The failure of
any seller and, if applicable, its parent company, to satisfy
their obligations with respect to claims and retained
liabilities covered by the acquisition agreements could have an
adverse effect on our results of operations and financial
position if claimants successfully assert that we are liable for
those claims and/or retained liabilities. The obligations of the
sellers and, in some instances, their parent companies, to
indemnify us with respect to their retained liabilities will
continue for a substantial period of time, and in some cases
indefinitely. The sellers indemnification obligations with
respect to breaches of their representations and warranties in
the acquisition agreements will terminate upon expiration of the
applicable indemnification period (generally 18-24 months
from the acquisition date for most representations and
warranties, and from two to five years from the acquisition date
for environmental representations and warranties), are subject
to deductible amounts and will not cover damages in excess of
the applicable coverage limit. The assertion of third-party
claims after the expiration of the applicable indemnification
period or in excess of the applicable coverage limit, or the
failure of any seller to satisfy its indemnification obligations
with respect to breaches of its representations and warranties,
could have an adverse effect on our results of operations and
financial position. See If our assumptions
regarding our likely future expenses related to benefits for
non-active employees are incorrect, then expenditures for these
benefits could be materially higher than we have predicted.
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Our inability to continue or expand the existing road
construction and mining business of the Nicewonder Companies
could adversely affect the expected benefits from the Nicewonder
Acquisition. |
One of our subsidiaries acquired the business of Nicewonder
Contracting, Inc. (NCI) pursuant to the Nicewonder
Acquisition. NCI operates a highway construction business under
a contract with the State of West Virginia. Pursuant to the
contract, NCI is building approximately 11 miles of rough
grade highway in West Virginia over the next six years and, in
exchange NCI will be compensated by West Virginia based on the
number of cubic yards of material excavated and/or filled to
create a road bed, as well as for certain other cost components.
In the course of the road construction, NCI will recover any
coal encountered and sell the coal to its customers, subject to
certain costs including coal loading, transportation, coal
royalty payments and applicable taxes and fees.
This road construction operation is in its early stages and the
State of West Virginia has only approved funding for the first
phases of highway construction. If West Virginia does not fund
the remaining sections of the highway project, it would
adversely affect NCIs earnings. Even if West Virginia
funds the remainder of this project through the next six years,
we are uncertain whether the state will fund any similar
projects in the future. In addition, we have no current
experience conducting and completing road projects and will rely
on the expertise of the existing employees of NCI in order to
operate the project, and other road projects we may undertake,
profitably. Furthermore, litigation has been filed against NCI
and the State of West Virginia claiming that the project
violated competitive bidding and prevailing wage laws and
regulations. If successful, the litigation could make the
project considerably less advantageous to NCI or restrict or
prohibit NCI from completing the project.
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The loss of, or significant reduction in, purchases by our
largest customers could adversely affect our revenues and
profitability. |
Our largest customer during 2004 accounted for approximately 8%
of our total revenues. We derived approximately 39% of our 2004
total revenues from sales to our ten largest customers. The
sales of the Nicewonder Coal Group are highly concentrated, with
approximately 78% of the Nicewonder Coal Groups coal
revenues during the year ended December 31, 2004 generated
from sales to three customers. On a pro forma basis as if the
Nicewonder Acquisition had occurred on January 1, 2004, our
largest customer during 2004 would have accounted for
approximately 8% of our total revenues and we would have derived
approximately 37% of our 2004 total revenues from sales to our
ten largest customers. These customers may not continue to
purchase coal from us under our current coal supply agreements,
or at all. If these customers were to significantly reduce their
purchases of coal from us, or if we were unable to sell coal to
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them on terms as favorable to us as the terms under our current
agreements, our revenues and profitability could suffer
materially.
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Changes in purchasing patterns in the coal industry may
make it difficult for us to extend existing supply contracts or
enter into new long-term supply contracts with customers, which
could adversely affect the capability and profitability of our
operations. |
We sell a significant portion of our coal under long-term coal
supply agreements, which are contracts with a term greater than
12 months. The execution of a satisfactory long-term coal
supply agreement is frequently the basis on which we undertake
the development of coal reserves required to be supplied under
the contract. We believe that approximately 73% of our 2004
sales volume was sold under long-term coal supply agreements. At
November 1, 2005, our long-term coal supply agreements had
remaining terms of up to 11 years and an average remaining
term of approximately two years. When our current contracts with
customers expire or are otherwise renegotiated, our customers
may decide to purchase fewer tons of coal than in the past or on
different terms, including pricing terms less favorable to us.
As of December 31, 2005, approximately 12%, 54% and 77%,
respectively, of our planned production for 2006, 2007 and 2008,
including production from the operations we acquired in the
Nicewonder Acquisition, was uncommitted. We may not be able to
enter into coal supply agreements to sell this production on
terms, including pricing terms, as favorable to us as our
existing agreements. For additional information relating to our
long-term coal supply contracts, see Business
Marketing, Sales and Customer Contracts.
As electric utilities continue to adjust to frequently changing
regulations, including the Acid Rain regulations of the Clean
Air Act, the Clean Air Mercury Rule, the Clean Air Interstate
Rule and the possible deregulation of their industry, they are
becoming increasingly less willing to enter into long-term coal
supply contracts and instead are purchasing higher percentages
of coal under short-term supply contracts. The industry shift
away from long-term supply contracts could adversely affect us
and the level of our revenues. For example, fewer electric
utilities will have a contractual obligation to purchase coal
from us, thereby increasing the risk that we will not have a
market for our production. The prices we receive in the spot
market may be less than the contractual price an electric
utility is willing to pay for a committed supply. Furthermore,
spot market prices tend to be more volatile than contractual
prices, which could result in decreased revenues.
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Certain provisions in our long-term supply contracts may
reduce the protection these contracts provide us during adverse
economic conditions or may result in economic penalties upon our
failure to meet specifications. |
Price adjustment, price reopener and other similar
provisions in long-term supply contracts may reduce the
protection from short-term coal price volatility traditionally
provided by these contracts. Price reopener provisions are
particularly common in international metallurgical coal sales
contracts. Some of our coal supply contracts contain provisions
that allow for the price to be renegotiated at periodic
intervals. Price reopener provisions may automatically set a new
price based on the prevailing market price or, in some
instances, require the parties to agree on a new price,
sometimes between a pre-set floor and
ceiling. In some circumstances, failure of the
parties to agree on a price under a price reopener provision can
lead to termination of the contract. Any adjustment or
renegotiation leading to a significantly lower contract price
could result in decreased revenues. Accordingly, supply
contracts with terms of one year or more may provide only
limited protection during adverse market conditions.
Coal supply agreements also typically contain force majeure
provisions allowing temporary suspension of performance by us or
the customer during the duration of specified events beyond the
control of the affected party. Most of our coal supply
agreements contain provisions requiring us to deliver coal
meeting quality thresholds for certain characteristics such as
Btu, sulfur content, ash content, grindability and ash fusion
temperature. Failure to meet these specifications could result
in economic penalties, including price adjustments, the
rejection of deliveries or termination of the contracts.
Moreover, some of our agreements where the customer bears
transportation costs permit the customer to terminate the
contract if the transportation costs borne by them increase
substantially. In addition, some of these contracts allow our
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customers to terminate their contracts in the event of changes
in regulations affecting our industry that increase the price of
coal beyond specified limits.
Due to the risks mentioned above with respect to long-term
supply contracts, we may not achieve the revenue or profit we
expect to achieve from these sales commitments.
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Disruption in supplies of coal produced by contractors and
other third parties could temporarily impair our ability to fill
customers orders or increase our costs. |
In addition to marketing coal that is produced by our
subsidiaries employees, we utilize contractors to operate
some of our mines. Operational difficulties at
contractor-operated mines, changes in demand for contract miners
from other coal producers, and other factors beyond our control
could affect the availability, pricing, and quality of coal
produced for us by contractors. For example, during the third
quarter of 2005, production at our contractor operations was
running approximately 28% behind plan, primarily due to
shortages in the supply of labor. As a result of this shortfall,
we have been forced to purchase coal at a higher cost than
planned so that we can meet commitments to customers. To meet
customer specifications and increase efficiency in fulfillment
of coal contracts, we also purchase and resell coal produced by
third parties from their controlled reserves. The majority of
the coal that we purchase from third parties is blended with
coal produced from our mines prior to resale and we also process
(which includes washing, crushing or blending coal at one of our
preparation plants or loading facilities) a portion of the coal
that we purchase from third parties prior to resale. We sold
7.3 million tons of coal purchased from third parties
during 2004, representing 28% of our total sales during 2004. We
believe that approximately 81% of our purchased coal sales in
2004 was blended with coal produced from our mines prior to
resale, and approximately 3% of our total sales in 2004
consisted of coal purchased from third parties that we processed
before resale. The availability of specified qualities of this
purchased coal may decrease and prices may increase as a result
of, among other things, changes in overall coal supply and
demand levels, consolidation in the coal industry and new laws
or regulations. Disruption in our supply of contractor-produced
coal and purchased coal could temporarily impair our ability to
fill our customers orders or require us to pay higher
prices in order to obtain the required coal from other sources.
Any increase in the prices we pay for contractor-produced coal
or purchased coal could increase our costs and therefore lower
our earnings. Although increases in market prices for coal
generally benefit us by allowing us to sell coal at higher
prices, those increases also increase our costs to acquire
purchased coal, which lowers our earnings.
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Competition within the coal industry may adversely affect
our ability to sell coal, and excess production capacity in the
industry could put downward pressure on coal prices. |
We compete with numerous other coal producers in various regions
of the United States for domestic and international sales.
During the mid-1970s and early 1980s, increased demand for coal
attracted new investors to the coal industry, spurred the
development of new mines and resulted in additional production
capacity throughout the industry, all of which led to increased
competition and lower coal prices. Recent increases in coal
prices could encourage the development of expanded capacity by
new or existing coal producers. Any resulting overcapacity could
reduce coal prices and therefore reduce our revenues.
Coal with lower production costs shipped east from western coal
mines and from offshore sources has resulted in increased
competition for coal sales in the Appalachian region. In
addition, coal companies with larger mines that utilize the
long-wall mining method typically have lower mine operating
costs than we do and may be able to compete more effectively on
price, particularly if the current favorable market weakens.
This competition could result in a decrease in our market share
in this region and a decrease in our revenues.
Demand for our low sulfur coal and the prices that we can obtain
for it are also affected by, among other things, the price of
emissions allowances. Decreases in the prices of these emissions
allowances could make low sulfur coal less attractive to our
customers. In addition, more widespread installation by electric
utilities of technology that reduces sulfur emissions (which
could be accelerated by increases in the prices
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of emissions allowances), may make high sulfur coal more
competitive with our low sulfur coal. This competition could
adversely affect our business and results of operations.
We also compete in international markets against coal produced
in other countries. Measured by tons sold, exports accounted for
approximately 32% of our sales in 2004. The demand for
U.S. coal exports is dependent upon a number of factors
outside of our control, including the overall demand for
electricity in foreign markets, currency exchange rates, the
demand for foreign-produced steel both in foreign markets and in
the U.S. market (which is dependent in part on tariff rates
on steel), general economic conditions in foreign countries,
technological developments, and environmental and other
governmental regulations. For example, if the value of the
U.S. dollar were to rise against other currencies in the
future, our coal would become relatively more expensive and less
competitive in international markets, which could reduce our
foreign sales and negatively impact our revenues and net income.
In addition, if the amount of coal exported from the United
States were to decline, this decline could cause competition
among coal producers in the United States to intensify,
potentially resulting in additional downward pressure on
domestic coal prices.
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Fluctuations in transportation costs and the availability
or reliability of transportation could affect the demand for our
coal or temporarily impair our ability to supply coal to our
customers. |
Transportation costs represent a significant portion of the
total cost of coal for our customers. Increases in
transportation costs, such as those experienced during the first
nine months of 2005, could make coal a less competitive source
of energy or could make our coal production less competitive
than coal produced from other sources. On the other hand,
significant decreases in transportation costs could result in
increased competition from coal producers in other parts of the
country. For instance, coordination of the many eastern loading
facilities, the large number of small shipments, terrain and
labor issues all combine to make shipments originating in the
eastern United States inherently more expensive on a per-mile
basis than shipments originating in the western United States.
Historically, high coal transportation rates from the western
coal producing areas into Central Appalachian markets limited
the use of western coal in those markets. More recently,
however, lower rail rates from the western coal producing areas
to markets served by eastern U.S. producers have created
major competitive challenges for eastern producers. This
increased competition could have a material adverse effect on
our business, financial condition and results of operations.
We depend upon railroads, trucks, beltlines, ocean vessels and
barges to deliver coal to our customers. Disruption of these
transportation services due to weather-related problems,
mechanical difficulties, strikes, lockouts, bottlenecks, and
other events could temporarily impair our ability to supply coal
to our customers, resulting in decreased shipments. Certain
shipments of our coal to customers were delayed by the recent
hurricanes in the Gulf Coast. In some cases, this delay will
affect the timing of our recognition of revenue from these
sales. Decreased performance levels over longer periods of time
could cause our customers to look to other sources for their
coal needs, negatively affecting our revenues and profitability.
In 2004, 79% of our produced and processed coal volume was
transported from the preparation plant to the customer by rail.
Beginning in the Spring of 2004, we have experienced a general
deterioration in the reliability of the service provided by rail
carriers, which increased our internal coal handling costs. If
there are continued disruptions of the transportation services
provided by the railroad companies we use and we are unable to
find alternative transportation providers to ship our coal, our
business could be adversely affected.
We have investments in mines, loading facilities, and ports that
in most cases are serviced by a single rail carrier. Our
operations that are serviced by a single rail carrier are
particularly at risk to disruptions in the transportation
services provided by that rail carrier, due to the difficulty in
arranging alternative transportation. If a single rail carrier
servicing our operations does not provide sufficient capacity,
revenue from these operations and our return on investment could
be adversely impacted.
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The states of West Virginia and Kentucky have recently increased
enforcement of weight limits on coal trucks on their public
roads. It is possible that other states in which our coal is
transported by truck could undertake similar actions to increase
enforcement of weight limits. Such stricter enforcement actions
could result in shipment delays and increased costs. An increase
in transportation costs could have an adverse effect on our
ability to increase or to maintain production on a profit-making
basis and could therefore adversely affect revenues and earnings.
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Our business will be adversely affected if we are unable
to develop or acquire additional coal reserves that are
economically recoverable. |
Our profitability depends substantially on our ability to mine
coal reserves possessing quality characteristics desired by our
customers in a cost-effective manner. As of July 31, 2005,
on a pro forma basis giving effect to the Nicewonder
Acquisition, we owned or leased 518.9 million tons of
proven and probable coal reserves that we believe will support
current production levels for more than 20 years, which is
less than the publicly reported amount of proven and probable
coal reserves and reserve lives (based on current publicly
reported production levels) of the other large publicly traded
coal companies. We have not yet applied for the permits
required, or developed the mines necessary, to mine all of our
reserves. Permits are becoming increasingly more difficult and
expensive to obtain and the review process continues to
lengthen. In addition, we may not be able to mine all of our
reserves as profitably as we do at our current operations.
Because our reserves decline as we mine our coal, our future
success and growth depend, in part, upon our ability to acquire
additional coal reserves that are economically recoverable. If
we are unable to replace or increase our coal reserves on
acceptable terms, our production and revenues will decline as
our reserves are depleted. Exhaustion of reserves at particular
mines also may have an adverse effect on our operating results
that is disproportionate to the percentage of overall production
represented by such mines. Our ability to acquire additional
coal reserves through acquisitions in the future also could be
limited by restrictions under our existing or future debt
agreements, competition from other coal companies for attractive
properties, or the lack of suitable acquisition candidates.
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We face numerous uncertainties in estimating our
recoverable coal reserves, and inaccuracies in our estimates
could result in decreased profitability from lower than expected
revenues or higher than expected costs. |
Forecasts of our future performance are based on, among other
things, estimates of our recoverable coal reserves. We base our
estimates of reserve information on engineering, economic and
geological data assembled and analyzed by our internal engineers
and which is periodically reviewed by third-party consultants.
There are numerous uncertainties inherent in estimating the
quantities and qualities of, and costs to mine, recoverable
reserves, including many factors beyond our control. Estimates
of economically recoverable coal reserves and net cash flows
necessarily depend upon a number of variable factors and
assumptions, any one of which may, if incorrect, result in an
estimate that varies considerably from actual results. These
factors and assumptions include:
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future coal prices, operating costs, capital expenditures,
severance and excise taxes, royalties and development and
reclamation costs; |
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future mining technology improvements; |
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the effects of regulation by governmental agencies; and |
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geologic and mining conditions, which may not be fully
identified by available exploration data and may differ from our
experiences in areas we currently mine. |
As a result, actual coal tonnage recovered from identified
reserve areas or properties, and costs associated with our
mining operations, may vary from estimates. Any inaccuracy in
our estimates related to our reserves could result in decreased
profitability from lower than expected revenues or higher than
expected costs.
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Defects in title of any leasehold interests in our
properties could limit our ability to mine these properties or
result in significant unanticipated costs. |
We conduct a significant part of our mining operations on
properties that we lease. Title to most of our leased properties
and mineral rights is not thoroughly verified until a permit to
mine the property is obtained, and in some cases title with
respect to leased properties is not verified at all. Our right
to mine some of our reserves may be materially adversely
affected by defects in title or boundaries. In order to obtain
leases or mining contracts to conduct our mining operations on
property where these defects exist, we may in the future have to
incur unanticipated costs, which could adversely affect our
profitability.
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Mining in Central and Northern Appalachia is more complex
and involves more regulatory constraints than mining in other
areas of the United States, which could affect our mining
operations and cost structures in these areas. |
The geological characteristics of Central and Northern
Appalachian coal reserves, such as depth of overburden and coal
seam thickness, make them complex and costly to mine. As mines
become depleted, replacement reserves may not be available when
required or, if available, may not be capable of being mined at
costs comparable to those characteristic of the depleting mines.
In addition, as compared to mines in other regions, permitting,
licensing and other environmental and regulatory requirements
are more costly and time consuming to satisfy. These factors
could materially adversely affect the mining operations and cost
structures of, and our customers ability to use coal
produced by, our mines in Central and Northern Appalachia.
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Our work force could become increasingly unionized in the
future, which could adversely affect the stability of our
production and reduce our profitability. |
Approximately 95% of our 2004 coal production came from mines
operated by union-free employees. As of November 1, 2005,
over 91% of our subsidiaries approximately 3,240 employees
are union-free. However, our subsidiaries employees have
the right at any time under the National Labor Relations Act to
form or affiliate with a union. Any further unionization of our
subsidiaries employees, or the employees of third-party
contractors who mine coal for us, could adversely affect the
stability of our production and reduce our profitability.
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Our unionized work force could strike in the future, which
could disrupt production and shipments of our coal and increase
costs. |
One of our subsidiaries has two negotiated wage agreements with
the United Mine Workers of America (UMWA). These
agreements, covering approximately 243 employees as of
November 1, 2005, expire on December 31, 2009. Two of
our other subsidiaries have negotiated wage agreements with the
UMWA covering an aggregate of 30 employees as of
November 1, 2005 that will expire in December 2006. Some or
all of the affected employees at each location could strike,
which would adversely affect our productivity, increase our
costs, and disrupt shipments of coal to our customers.
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Our ability to collect payments from our customers could
be impaired if their creditworthiness deteriorates. |
Our ability to receive payment for coal sold and delivered
depends on the continued creditworthiness of our customers.
During 2004, we had $152,000 of bad debt expense. Our customer
base is changing with deregulation as utilities sell their power
plants to their non-regulated affiliates or third parties that
may be less creditworthy, thereby increasing the risk we bear on
payment default. These new power plant owners may have credit
ratings that are below investment grade. In addition,
competition with other coal suppliers could force us to extend
credit to customers and on terms that could increase the risk we
bear on payment default.
We have contracts to supply coal to energy trading and brokering
companies under which those companies sell coal to end users. If
the creditworthiness of the energy trading and brokering
companies
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declines, this would increase the risk that we may not be able
to collect payment for all coal sold and delivered to or on
behalf of these energy trading and brokering companies.
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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 and sell coal. |
The coal mining industry is subject to increasingly strict
regulation by federal, state and local authorities with respect
to matters such as:
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employee health and safety; |
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mandated benefits for retired coal miners; |
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mine permitting and licensing requirements; |
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reclamation and restoration of mining properties after mining is
completed; |
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air quality standards; |
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water pollution; |
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plant and wildlife protection; |
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the discharge of materials into the environment; |
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surface subsidence from underground mining; and |
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the effects of mining on groundwater quality and availability. |
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. Failure to comply with these regulations may result
in the assessment of administrative, civil and criminal
penalties, the imposition of cleanup and site restoration costs
and liens, the issuance of injunctions to limit or cease
operations, the suspension or revocation of permits and other
enforcement measures that could have the effect of limiting
production from our operations. We may also incur costs and
liabilities resulting from claims for damages to property or
injury to persons arising from our operations. If we are pursued
for these sanctions, costs and liabilities, our mining
operations and, as a result, our profitability could be
adversely affected.
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 new judicial interpretations or
administrative enforcement 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. These regulations, if proposed and
enacted in the future, could have a material adverse effect on
our financial condition and results of operations.
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Extensive environmental regulations affect our customers
and could reduce the demand for coal as a fuel source and cause
our sales to decline. |
The Clean Air Act and similar state and local laws extensively
regulate the amount of sulfur dioxide, particulate matter,
nitrogen oxides, and other compounds emitted into the air from
electric power plants, which are the largest end-users of our
coal. Such regulations will require significant emissions
control expenditures for many coal-fired power plants to comply
with applicable ambient air quality standards. As a result,
these generators may switch to other fuels that generate less of
these emissions or install more effective pollution control
equipment, possibly reducing future demand for coal and the
construction of coal-fired power plants.
Various new and proposed laws and regulations may require
further reductions in emissions from coal-fired utilities. For
example, under the new Clean Air Interstate Rule issued on
March 10, 2005, the EPA
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will further regulate sulfur dioxide and nitrogen oxides from
coal-fired power plants. When fully implemented, this rule is
expected to reduce sulfur dioxide emissions in affected states
by over 70% and nitrogen oxides emissions by over 60% from 2003
levels. The stringency of this cap may require many coal-fired
sources to install additional pollution control equipment, such
as wet scrubbers, to comply. Installation of additional
pollution control equipment required by this rule could result
in a decrease in the demand for low sulfur coal (because sulfur
would be removed by the new emissions control equipment),
potentially driving down prices for low sulfur coal. In
addition, under the Clean Air Act, coal-fired power plants will
be required to control hazardous air pollution emissions by no
later than 2009, which likely will require significant new
investment in pollution-control devices by power plant
operators. Further, on March 15, 2005, the EPA finalized
the Clean Air Mercury Rule intended to control mercury emissions
from power plants, which could require coal-fired power plants
to install new pollution controls or comply with a mandatory,
declining cap on the total mercury emissions allowed from
coal-fired power plants nationwide. Both the Clean Air Mercury
Rule and the Clean Air Interstate Rule are subject to
administrative reconsideration and judicial challenge. These
standards and future standards could have the effect of making
coal-fired plants unprofitable, thereby decreasing demand for
coal. 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 purchasers plant or results in
specified increases in the cost of coal or its use.
Several proposals are pending in Congress and various states
that are designed to further reduce emissions of sulfur dioxide,
nitrogen oxides and mercury from power plants, and certain ones
could regulate additional air pollutants. If such initiatives
are enacted into law, power plant operators could choose fuel
sources other than coal to meet their requirements, thereby
reducing the demand for coal. Current and possible future
governmental programs are or may be in place to require the
purchase and trading of allowances associated with the emission
of various substances such as sulfur dioxide, nitrous oxide,
mercury and carbon dioxide. Changes in the markets for and
prices of allowances could have a material effect on demand for
and prices received for our coal.
A regional haze program initiated by the EPA to protect and to
improve visibility at and around national parks, national
wilderness areas and international parks restricts the
construction of new coal-fired power plants whose operation may
impair visibility at and around federally protected areas, and
may require some existing coal-fired power plants, and certain
thermal dryers, to install additional control measures designed
to limit haze-causing emissions.
One major by-product of burning coal is carbon dioxide, which is
considered a greenhouse gas and is a major source of concern
with respect to global warming. In November 2004, Russia
ratified the Kyoto Protocol to the 1992 Framework Convention on
Global Climate Change (the Protocol), which
establishes a binding set of emission targets for greenhouse
gases. With Russias accedence, the Protocol now has
sufficient support and became binding on all those countries
that have ratified it on February 16, 2005. Four
industrialized nations have refused to ratify the
Protocol Australia, Liechtenstein, Monaco, and the
United States. Although the targets vary from country to
country, if the United States were to ratify the Protocol, our
nation would be required to reduce greenhouse gas emissions to
93% of 1990 levels in a series of phased reductions from 2008 to
2012. Canada, which accounted for approximately 6% of our 2004
sales volume, ratified the Protocol in 2002. Under the Protocol,
Canada will be required to cut greenhouse gas emissions to 6%
below 1990 levels in a series of phased reductions from 2008 to
2012, either in direct reductions in emissions or by obtaining
credits through the Protocols market mechanisms. This
could result in reduced demand for coal by Canadian electric
power generators.
Future regulation of greenhouse gases in the United States could
occur pursuant to future U.S. treaty obligations, statutory
or regulatory changes under the Clean Air Act, or otherwise. The
Bush Administration has proposed a package of voluntary emission
reductions for greenhouse gases reduction targets which provide
for certain incentives if targets are met. Some states, such as
Massachusetts, have already issued regulations regulating
greenhouse gas emissions from large power plants. Further, in
2002, the Conference of New England Governors and Eastern
Canadian Premiers adopted a Climate Change Action Plan, calling
for reduction in regional greenhouse emissions to 1990 levels by
2010, and a further
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reduction of at least 10% below 1990 levels by 2020. Increased
efforts to control greenhouse gas emissions, including the
future ratification of the Protocol by the United States, could
result in reduced demand for our coal. See Environmental
and Other Regulatory Matters.
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Our operations may impact the environment or cause
exposure to hazardous substances, and our properties may have
environmental contamination, which could result in material
liabilities to us. |
Our operations currently use hazardous materials and generate
limited quantities of hazardous wastes from time to time. Our
Predecessor and acquired companies also utilized certain
hazardous materials and generated similar wastes. We may be
subject to claims under federal and state statutes and/or common
law doctrines for toxic torts, natural resource damages and
other damages as well as for the investigation and clean up of
soil, surface water, groundwater, and other media. Such claims
may arise, for example, out of current or former conditions at
sites that we own or operate currently, as well as at sites that
we or our Predecessor and acquired companies owned or operated
in the past, and at contaminated sites that have always been
owned or operated by third parties. Our liability for such
claims may be joint and several, so that we may be held
responsible for more than our share of the contamination or
other damages, or even for the entire share. We have not been
subject to claims arising out of contamination at our
facilities, and are not aware of any such contamination, but may
incur such liabilities in the future.
We maintain extensive coal slurry impoundments at a number of
our mines. Such impoundments are subject to extensive
regulation. Slurry impoundments maintained by other coal mining
operations have been known to fail, releasing large volumes of
coal slurry. Structural failure of an impoundment can result in
extensive damage to the environment and natural resources, such
as streams or bodies of water that the coal slurry reaches, as
well as liability for related personal injuries and property
damages, and injuries to wildlife. Some of our impoundments
overlie mined out areas, which can pose a heightened risk of
failure and of damages arising out of failure. If one of our
impoundments were to fail, we could be subject to substantial
claims for the resulting environmental contamination and
associated liability, as well as for fines and penalties.
These and other similar unforeseen impacts that our operations
may have on the environment, as well as exposures to hazardous
substances or wastes associated with our operations, could
result in costs and liabilities that could materially and
adversely affect us.
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We may be unable to obtain and renew permits necessary for
our operations, which would reduce our production, cash flow and
profitability. |
Mining companies must obtain numerous permits that impose strict
regulations on various environmental and safety matters in
connection with coal mining. These include permits issued by
various federal and state agencies and regulatory bodies. The
permitting rules are complex and may change over time, making
our ability to comply with the applicable requirements more
difficult or even impossible, thereby precluding continuing or
future mining operations. Private individuals and the public
have certain rights to comment upon, submit objections to, and
otherwise engage in the permitting process, including through
court intervention. Accordingly, the permits we need may not be
issued, maintained or renewed, or may not be issued or renewed
in a timely fashion, or may involve requirements that restrict
our ability to conduct our mining operations. An inability to
conduct our mining operations pursuant to applicable permits
would reduce our production, cash flow, and profitability.
Permits under Section 404 of the Clean Water Act are
required for coal companies to conduct dredging or filling
activities in jurisdictional waters for the purpose of creating
slurry ponds, water impoundments, refuse areas, valley fills or
other mining activities. The Army Corps of Engineers (the
COE) is empowered to issue nationwide
permits for specific categories of filling activity that are
determined to have minimal environmental adverse effects in
order to save the cost and time of issuing individual permits
under Section 404. Nationwide Permit 21 authorizes the
disposal of dredge-and-fill material from mining activities into
the waters of the United States. On October 23, 2003,
several citizens groups sued the COE in the U.S. District
Court for the Southern District of West Virginia seeking to
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invalidate nationwide permits utilized by the COE
and the coal industry for permitting most in-stream disturbances
associated with coal mining, including excess spoil valley fills
and refuse impoundments. Although the lower court enjoined the
issuance of Nationwide 21 permits, that decision was
overturned by the Fourth Circuit Court of Appeals, which
concluded that the COE complied with the Clean Water Act in
promulgating this permit. Although we had no operations that
were immediately impacted or interrupted, the lower courts
decision required us to convert certain current and planned
applications for Nationwide 21 permits to applications for
individual permits. A similar lawsuit was filed on
January 27, 2005 in the U.S. District Court for the
Eastern District of Kentucky remains pending, and other lawsuits
may be filed in other states where we operate. Although it is
not possible to predict the results of the Kentucky litigation,
it could adversely affect our Kentucky operations.
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We may not be able to implement required public-company
internal controls over financial reporting in the required time
frame or with adequate compliance, and implementation of the
controls will increase our costs. |
Our current operations consist primarily of the assets of our
Predecessor and the other operations we have acquired, each of
which had different historical operating, financial, accounting
and other systems. Due to our rapid growth and limited history
operating our acquired operations as an integrated business, our
internal control over financial reporting does not currently
meet all the standards contemplated by Section 404 of the
Sarbanes-Oxley Act that we will eventually be required to meet.
Areas of deficiency in our internal control over financial
reporting requiring improvement include: documentation of
controls and procedures; segregation of duties; timely
reconciliation of accounts; methods of reconciling fixed asset
accounts; the structure of our general ledger, security systems
and testing of our disaster recovery plan for our information
technology systems; and the level of experience in public
company accounting and periodic reporting matters among our
financial and accounting staff. Certain of these deficiencies
have resulted in out-of-period adjustments to our financial
statements. Although we have determined that such adjustments
have been immaterial, continued deficiencies in our internal
control over financial reporting may result in future
out-of-period adjustments, which could be material and require
us to restate our financial statements. In addition, in
connection with our integration of the Nicewonder Coal
Groups operations, we will also be required to assess and
make any necessary adjustments to the Nicewonder Coal
Groups internal controls and procedures. If we are not
able to implement the requirements of Section 404 in a
timely manner or with adequate compliance, our independent
auditors may not be able to certify as to the adequacy of our
internal controls over financial reporting. This result may
subject us to adverse regulatory consequences, and there could
also be a negative reaction in the financial markets due to a
loss of confidence in the reliability of our financial
statements. We could also suffer a loss of confidence in the
reliability of our financial statements if our auditors report a
material weakness in our internal controls. We will incur
incremental costs in order to comply with Section 404,
including increased auditing and legal fees and costs associated
with hiring additional accounting and administrative staff with
experience managing public companies.
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Our ability to operate our company effectively could be
impaired if we fail to attract and retain key personnel. |
Our ability to operate our business and implement our strategies
depends, in part, on the efforts of our executive officers and
other key employees. In addition, our future success will depend
on, among other factors, our ability to attract and retain other
qualified personnel. The successful integration of the
Nicewonder Coal Group also requires us to, among other things,
retain key employees. Our future performance depends, in part,
on our ability to successfully integrate these new employees
into our company. The loss of the services of any of our
executive officers or other key employees or the inability to
attract or retain other qualified personnel in the future could
have a material adverse effect on our business or business
prospects.
Certain of our subsidiaries have entered into employment
agreements with two of our executive officers
Michael J. Quillen, our Chief Executive Officer, and
D. Scott Kroh, one of our Executive Vice
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Presidents. Each of our other executive officers are employed on
an at-will basis. Unless extended, the employment agreements
between Messrs. Quillen and Kroh and our subsidiaries
terminate on March 11, 2006. When the terms of these
agreements expire, we may not be able to renew or extend these
employment agreements on terms acceptable to us. In addition,
the employment agreements with Mr. Quillen and
Mr. Kroh provide that if either executive resigns for
employee cause (as defined in the applicable
agreement), we will be required to pay the executive his earned
but unpaid salary through the date of termination, and to
continue to pay his then current base salary for the following
twelve months, and the executive would be entitled to
receive any bonuses payable for prior years, plus the pro rata
bonus payable for the current year, at the same time as bonuses
are paid to similarly situated employees. The employment
agreements with Mr. Quillen and Mr. Kroh provide that
a resignation by either executive for employee cause
includes, among other things, the executives resignation
during the period beginning three months, and ending nine months
following the liquidation or sale by First Reserve of more than
75% of its ownership in ANR Holdings and its affiliates, which
would result from First Reserve holding less than approximately
8,460,921 shares of our common stock after such a sale or
liquidation.
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A shortage of skilled labor in the Appalachian region
could pose a risk to achieving improved labor productivity and
competitive costs and could adversely affect our
profitability. |
Efficient coal mining using modern techniques and equipment
requires skilled laborers, preferably with at least a year of
experience and proficiency in multiple mining tasks. In recent
years, a shortage of trained coal miners in the Appalachian
region has caused us to operate certain units without full
staff, which decreases our productivity and increases our costs.
For example, during the third quarter of 2005, production at our
contractor operations was running approximately 28% behind plan,
primarily due to shortages in the supply of labor. If the
shortage of experienced labor continues or worsens, it could
have an adverse impact on our labor productivity and costs and
our ability to expand production in the event there is an
increase in the demand for our coal, which could adversely
affect our profitability.
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Our significant indebtedness could harm our business by
limiting our available cash and our access to additional capital
and could force us to sell material assets or take other actions
to attempt to reduce our indebtedness. |
We are a highly leveraged company. Our financial performance
could be affected by our significant indebtedness. At
September 30, 2005, we had approximately
$261.0 million of indebtedness outstanding, representing
66% of our total capitalization. This indebtedness consisted of
$175.0 million principal of our 10% senior notes due
2012, $81.0 million of borrowings under our prior revolving
credit facility and $5.0 million of other indebtedness,
including $1.6 million of capital lease obligations
extending through March 2009, $0.6 million principal amount
in variable rate term notes maturing in April 2006 that we
incurred in connection with equipment financing and
$2.8 million payable to an insurance premium finance
company. In addition, under our prior credit facility we had
$53.0 million of letters of credit outstanding at
September 30, 2005.
In connection with the Nicewonder Acquisition, we refinanced all
outstanding indebtedness under our prior credit facility with a
new credit facility, which provides for up to
$525.0 million of borrowings, including a
$275.0 million revolving credit facility and a
$250.0 million term loan. In addition, under the terms of
the Nicewonder Acquisition, one of our indirect, wholly-owned
subsidiaries issued $221.0 million in promissory
installment notes, payable in two installments of which
$181.1 million was paid on November 2, 2005 and
$39.9 million is due on January 15, 2006. We may also
incur additional indebtedness in the future. On a pro forma
basis giving effect to the Nicewonder Acquisition and 2005
Financing, including payment of the first installment of the
notes issued to the Nicewonder Coal Group sellers, we would have
had approximately $525.2 million of indebtedness
outstanding as of September 30, 2005, representing 74% of
our total capitalization, approximately $65.5 million of
letters of credit outstanding and additional borrowing
availability of approximately $154.2 million.
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This level of indebtedness could have important consequences to
our business. For example, it could:
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increase our vulnerability to general adverse economic and
industry conditions; |
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make it more difficult to self-insure and obtain surety bonds or
letters of credit; |
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limit our ability to enter into new long-term sales contracts; |
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make it more difficult for us to pay interest and satisfy our
debt obligations, including our obligations with respect to the
notes; |
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require us to dedicate a substantial portion of our cash flow
from operations to payments on our indebtedness, thereby
reducing the availability of our cash flow to fund working
capital, capital expenditures, acquisitions and other general
corporate activities; |
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limit our ability to obtain additional financing to fund future
working capital, capital expenditures, research and development,
debt service requirements or other general corporate
requirements; |
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limit our flexibility in planning for, or reacting to, changes
in our business and in the coal industry; |
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place us at a competitive disadvantage compared to less
leveraged competitors; and |
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limit our ability to borrow additional funds. |
If our cash flows and capital resources are insufficient to fund
our debt service obligations or our requirements under our other
long-term liabilities, we may be forced to sell assets, seek
additional capital or seek to restructure or refinance our
indebtedness. These alternative measures may not be successful
and may not permit us to meet our scheduled debt service
obligations, including our obligations with respect to the
notes, or our requirements under our other long term
liabilities. In the absence of such operating results and
resources, we could face substantial liquidity problems and
might be required to sell material assets or operations to
attempt to meet our debt service and other obligations. Our new
credit facility and the indenture under which our senior notes
were issued restrict our ability to sell assets and use the
proceeds from the sales. We may not be able to consummate those
sales or to obtain the proceeds which we could realize from them
and these proceeds may not be adequate to meet any debt service
obligations then due. Furthermore, substantially all of our
material assets secure our indebtedness under our new credit
facility.
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Despite our current leverage, we may still be able to
incur substantially more debt. This could further exacerbate the
risks associated with our significant indebtedness. |
We may be able to incur substantial additional indebtedness in
the future. The terms of our new credit facility and the
indenture governing our senior notes do not prohibit us from
doing so. Our new credit facility provides for a revolving line
of credit of up to $275.0 million, of which approximately
$154.2 million was available as of September 30, 2005,
on a pro forma basis after giving effect to the Nicewonder
Acquisition and 2005 Financing, including payment of the first
installment of the notes issued to the Nicewonder Coal Group
sellers. The addition of new debt to our current debt levels,
could increase the related risks that we now face. For example,
the spread over the variable interest rate applicable to loans
under our credit facility is dependent on our leverage ratio,
and it would increase if our leverage ratio increases.
Additional drawings under our revolving line of credit could
also limit the amount available for letters of credit in support
of our bonding obligations, which we will require as we develop
and acquire new mines.
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The covenants in our credit facility and the indenture
governing the notes impose restrictions that may limit our
operating and financial flexibility. |
Our new credit facility and the indenture governing our senior
notes contain a number of significant restrictions and covenants
that limit our ability and our subsidiaries ability to,
among other things, incur additional indebtedness or enter into
sale and leaseback transactions, pay dividends, make redemptions
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repurchases of certain capital stock, make loans and
investments, create liens, engage in transactions with
affiliates and merge or consolidate with other companies or sell
substantially all of our assets.
These covenants could adversely affect our ability to finance
our future operations or capital needs or to execute preferred
business strategies. In addition, if we violate these covenants
and are unable to obtain waivers from our lenders, our debt
under these agreements would be in default and could be
accelerated by our lenders. If our indebtedness is accelerated,
we may not be able repay our debt or borrow sufficient funds to
refinance it. Even if we were able to obtain new financing, it
may not be on commercially reasonable terms, on terms that are
acceptable to us, or at all. If our debt is in default for any
reason, our business, financial condition and results of
operations could be materially and adversely affected.
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Failure to obtain or renew surety bonds on acceptable
terms could affect our ability to secure reclamation and coal
lease obligations, which could adversely affect our ability to
mine or lease coal. |
Federal and state laws require us to obtain surety bonds to
secure payment of certain long-term obligations such as mine
closure or reclamation costs, federal and state workers
compensation costs, coal leases and other obligations. These
bonds are typically renewable annually. Surety bond issuers and
holders may not continue to renew the bonds or may demand
additional collateral or other less favorable terms upon those
renewals. The ability of surety bond issuers and holders to
demand additional collateral or other less favorable terms has
increased as the number of companies willing to issue these
bonds has decreased over time. Our failure to maintain, or our
inability to acquire, surety bonds that are required by state
and federal law would affect our ability to secure reclamation
and coal lease obligations, which could adversely affect our
ability to mine or lease coal. That failure could result from a
variety of factors including, without limitation:
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lack of availability, higher expense or unfavorable market terms
of new bonds; |
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restrictions on availability of collateral for current and
future third-party surety bond issuers under the terms of our
credit facility or the indenture governing our senior
notes; and |
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the exercise by third-party surety bond issuers of their right
to refuse to renew the surety. |
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Failure to maintain capacity for required letters of
credit could limit our available borrowing capacity under our
credit facility, limit our ability to obtain or renew surety
bonds and negatively impact our ability to obtain additional
financing to fund future working capital, capital expenditure or
other general corporate requirements. |
At September 30, 2005, on a pro forma basis giving effect
to the Nicewonder Acquisition and 2005 Financing, we would have
had approximately $65.5 million of letters of credit in
place, of which $60.7 million would have served as
collateral for reclamation surety bonds and $4.8 million
would have secured miscellaneous obligations. Our new credit
facility provides for revolving commitments of up to
$275.0 million, all of which can be used to issue
additional letters of credit. In addition, obligations secured
by letters of credit may increase in the future. Any such
increase would limit our available borrowing capacity under our
current or future credit facilities and could negatively impact
our ability to obtain additional financing to fund future
working capital, capital expenditure or other general corporate
requirements. Moreover, if we do not maintain sufficient
borrowing capacity under our revolving credit facility for
additional letters of credit, we may be unable to obtain or
renew surety bonds required for our mining operations.
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If our assumptions regarding our likely future expenses
related to benefits for non-active employees are incorrect, then
expenditures for these benefits could be materially higher than
we have predicted. |
At the times that we acquired the assets of our Predecessor and
acquired companies, the Predecessor and acquired operations were
subject to long-term liabilities under a variety of benefit
plans and other arrangements with active and inactive employees.
We assumed a portion of these long-term obligations. The current
and non-current accrued portions of these long-term obligations,
as reflected in our
36
consolidated financial statements as of September 30, 2005,
included $22.2 million of postretirement medical
obligations and $6.5 million of self-insured workers
compensation obligations, and our accumulated postretirement
benefit obligation at December 31, 2004 is
$43.8 million. These obligations have been estimated based
on assumptions that are described in the notes to our
consolidated financial statements included elsewhere in this
prospectus. However, if our assumptions are incorrect, we could
be required to expend greater amounts than anticipated.
Several states in which we operate consider changes in
workers compensation laws from time to time, which, if
enacted, could adversely affect us. In addition, if any of the
sellers from whom we acquired our operations fail to satisfy
their indemnification obligations to us with respect to
postretirement claims and retained liabilities, then we could be
required to expend greater amounts than anticipated. See
The inability of the sellers of our
Predecessor and acquired companies to fulfill their
indemnification obligations to us under our acquisition
agreements could increase our liabilities and adversely affect
our results of operations. Moreover, under certain
acquisition agreements, we agreed to permit responsibility for
black lung claims related to the sellers former employees
who are employed by us for less than one year after the
acquisition to be determined in accordance with law (rather than
specifically assigned to one party or the other in the
agreements). We believe that the sellers remain liable as a
matter of law for black lung benefits for their former employees
who work for us for less than one year; however, an adverse
ruling on this issue could increase our exposure to black lung
benefit liabilities.
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Demand for our coal changes seasonally and could have an
adverse effect on the timing of our cash flows and our ability
to service our existing and future indebtedness. |
Our business is seasonal, with operating results varying from
quarter to quarter. We have historically experienced lower sales
during winter months primarily due to the freezing of lakes that
we use to transport coal to some of our customers. As a result,
our first quarter cash flow and profits have been, and may
continue to be, negatively impacted. Lower than expected sales
by us during this period could have a material adverse effect on
the timing of our cash flows and therefore our ability to
service our obligations with respect to our existing and future
indebtedness.
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Our earnings will be reduced in future periods as a result
of our issuance of shares of our common stock to members of
management as part of the Internal Restructuring. |
As part of the Internal Restructuring, our executive officers
and certain other key employees exchanged their interests in ANR
Holdings for shares of our common stock and the right to
participate in a distribution of the proceeds received by us
from the underwriters as a result of the underwriters
exercise of their over-allotment option in connection with the
IPO. As a result, we recorded stock-based compensation expense
equal to the fair value of the vested shares issued and
distributions paid in the amount of $42.6 million for the
nine months ended September 30, 2005. In addition, as a
result of the conversion of outstanding options held by members
of our management to purchase units of Alpha Coal Management
into options to purchase up to 596,985 shares of our common
stock in connection with the Internal Restructuring (the
ACM Converted Options), we recorded stock-based
compensation of $0.6 million for the first nine months
of 2005. The aggregate amount of stock-based compensation
expense and stock-based compensation we recorded in the first
nine months of 2005 was $43.2 million, equal to the
$42.6 million of expense associated with distributions paid
and the vested portions of shares issued in the Internal
Restructuring and amortization expense from the unvested
portions of shares issued in the Internal Restructuring, and
$0.6 million of amortization expense from the ACM Converted
Options. In addition, we had deferred stock-based compensation
at September 30, 2005 of $18.6 million, including
$16.0 million and $2.6 million associated with the
unvested portions of shares issued in the Internal Restructuring
and the ACM Converted Options, respectively, that we will record
as non-cash stock-based compensation expense over the remaining
term of the applicable two-year and five-year vesting periods,
respectively. The amortization of the deferred stock-based
compensation relating to the unvested shares issued in the
Internal Restructuring and the ACM converted options over the
applicable two-year and five-
37
year vesting periods will result in a non-cash amortization
expense in these periods, thereby reducing our earnings in those
periods.
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|
|
Our Sponsors may have significant influence on our company
and may have conflicts of interest with us or you in the
future. |
The First Reserve Stockholders and persons affiliated with AMCI
beneficially own approximately 39% of our outstanding common
stock as of January 1, 2006. We refer to First Reserve and
to AMCI and its affiliates, collectively, as our
Sponsors. After this offering, the First Reserve
Stockholders will beneficially own approximately 2.87% of our
common stock and persons affiliated with AMCI will beneficially
own approximately 17.62% of our common stock. If the
underwriters exercise in full their option to purchase
additional shares, the First Reserve Stockholders will not
beneficially own any shares of our common stock and persons
affiliated with AMCI will beneficially own approximately 17.62%
of our common stock. Our Sponsors are in the business of making
investments in companies and they may from time to time acquire
and hold interests in businesses that compete directly or
indirectly with us. For example, our Sponsors hold a combined
12.6% ownership interest in Foundation Coal Holdings, Inc.
(Foundation) as of September 30, 2005. These
other investments may create competing financial demands on our
Sponsors, potential conflicts of interest and require efforts
consistent with applicable law to keep the other businesses
separate from our operations. Our Sponsors may also pursue
acquisition opportunities that may be complementary to our
business, and as a result, those acquisition opportunities may
not be available to us. Additionally, our amended and restated
certificate of incorporation provides that our Sponsors may
compete with us. The designees of the persons affiliated with
AMCI on our board of directors, as well as the remaining
designee of the First Reserve Stockholders on our board of
directors for so long as he continues to serve as a director,
will not be required to offer corporate opportunities to us and
may take any such opportunities for themselves, other than any
opportunities offered to the designees solely in their capacity
as one of our directors. So long as our Sponsors continue to own
a significant amount of our equity, even if such amount is less
than 50%, they will continue to be able to strongly influence or
effectively control our decisions. For example, our Sponsors
could cause us to make acquisitions that increase our amount of
indebtedness or sell revenue-generating assets.
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|
|
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 and
those of our customers. 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 of these occurrences, or a combination
of them, could have a material adverse effect on our business,
financial condition and results of operations.
Risks Related to the Offering
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|
|
Future sales of our shares could depress the market price
of our common stock. |
The market price of our common stock could decline as a result
of sales of a large number of shares of common stock in the
market after the offering or the perception that such sales
could occur. These sales, or the possibility that these sales
may occur, also might make it more difficult for us to sell
equity securities in the future at a time and at a price that we
deem appropriate.
38
We, each of the selling stockholders and our directors and
executive officers have agreed with the underwriters not to
sell, dispose of or hedge any shares of our common stock or
securities convertible into or exchangeable for shares of our
common stock, subject to specified exceptions, during the period
from the date of this prospectus continuing through the date
that is 90 days after the date of this prospectus, except
with the prior written consent of Morgan Stanley & Co.
Incorporated, Citigroup Global Markets Inc. and UBS Securities
LLC.
As of January 1, 2006, we had outstanding
64,420,414 shares of common stock. Of those shares, the
14,163,527 shares being offered hereby (including shares
subject to the underwriters option), plus the
33,925,000 shares previously sold in our initial public
offering, as well as shares that have been resold since the IPO
pursuant to Rules 144 or 701 of the Securities Act or
issued by us pursuant to our registration statement on
Form S-8, are
freely tradeable without restriction or further registration
under the Securities Act, except that any shares held by our
affiliates, as that term is defined under
Rule 144, may be sold only in compliance with the
limitations of Rule 144. In addition,
13,147,040 shares (assuming the underwriters option
is exercised in full) will be eligible for resale from time to
time after the expiration of the
90-day
lock-up period, subject
to Securities Act restrictions, including those relating to the
volume, manner of sale and other conditions of Rule 144,
and, in the case of certain shares owned by management, the
conditions of Rule 701 and certain vesting agreements.
After the expiration of the
90-day
lock-up period, the
Sponsors and their affiliates, which will collectively
beneficially own 13,199,313 shares after this offering
assuming the underwriters option is not exercised, will
have the ability to cause us to register the resale of their
remaining shares.
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|
|
The market price of our common stock may be volatile,
which could cause the value of your investment to
decline. |
Securities markets worldwide experience significant price and
volume fluctuations. This market volatility, as well as general
economic, market or potential conditions, could reduce market
price of our common stock in spite of our operating performance.
In addition, our operating results could be below the
expectations of public market analysts and investors, and in
response, the market price of our common stock could decrease
significantly. You may be unable to resell your shares of our
common stock at or above the offering price.
Our ability to pay regular dividends to our stockholders
is subject to the discretion of our board of directors and may
be limited by our holding company structure, the covenants in
our debt instruments and applicable provisions of Delaware
law.
As discussed under Dividend Policy, we expect to
consider a policy of paying quarterly dividends beginning
sometime in 2006. Our board of directors may, in its discretion,
decide not to adopt this dividend policy or, if adopted, may
decrease the level of dividends or subsequently discontinue the
payment of dividends entirely. In addition, as a holding
company, we will be dependent upon the ability of our direct and
indirect subsidiaries to generate earnings and cash flows and
distribute them to intermediate parent companies and to us so
that we can pay dividends to our stockholders, as well as our
obligations and expenses. Our subsidiaries ability to make
such distributions will be subject to their operating results,
cash requirements and financial condition, the applicable laws
of the State of Delaware (which may limit the amount of funds
available for distribution to equity interest holders),
compliance with covenants and financial ratios related to
existing or future indebtedness, and other agreements with third
parties. If, as a consequence of these various limitations and
restrictions, we are unable to generate sufficient distributions
from our business, we may not be able to make, or may have to
reduce or eliminate, the payment of dividends on our shares.
39
|
|
|
Provisions in our certificate of incorporation and bylaws
may discourage a takeover attempt even if doing so might be
beneficial to our shareholders. |
Provisions contained in our certificate of incorporation and
bylaws could impose impediments to the ability of a third party
to acquire us even if a change of control would be beneficial to
our existing shareholders. Provisions of our certificate of
incorporation and bylaws impose various procedural and other
requirements, which could make it more difficult for
stockholders to effect certain corporate actions. For example,
our certificate of incorporation authorizes our board of
directors to determine the rights, preferences, privileges and
restrictions of unissued series of preferred stock, without any
vote or action by our stockholders. Thus, our board of directors
can authorize and issue shares of preferred stock with voting or
conversion rights that could adversely affect the voting or
other rights of holders of our common stock. These rights may
have the effect of delaying or deterring a change of control of
our company, and could limit the price that certain investors
might be willing to pay in the future for shares of our common
stock. See Description of Capital Stock.
40
SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS
This prospectus contains statements of our expectations,
intentions, plans and beliefs that constitute
forward-looking statements within the meaning of
Section 27A of the Securities Act of 1933 and
Section 21E of the Securities Exchange Act of 1934 and are
intended to come within the safe harbor protection provided by
those sections. These statements, which involve risks and
uncertainties, relate to analyses and other information that are
based on forecasts of future results and estimates of amounts
not yet determinable. These statements may also relate to our
future prospects, developments and business strategies.
We have used the words anticipate,
believe, could, estimate,
expect, intend, may,
plan, predict, project and
similar terms and phrases, including references to assumptions,
in this prospectus to identify forward-looking statements. These
forward-looking statements are made based on expectations and
beliefs concerning future events affecting us and are subject to
uncertainties and factors relating to our operations and
business environment, all of which are difficult to predict and
many of which are beyond our control, that could cause our
actual results to differ materially from those matters expressed
in or implied by these forward-looking statements.
We do not undertake any responsibility to release publicly any
revisions to these forward-looking statements to take into
account events or circumstances that occur after the date of
this prospectus. Additionally, we do not undertake any
responsibility to update you on the occurrence of any
unanticipated events which may cause actual results to differ
from those expressed or implied by the forward-looking
statements contained in this prospectus.
The following factors are among those that may cause actual
results to differ materially from our forward-looking statements:
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market demand for coal, electricity and steel; |
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future economic or capital market conditions; |
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weather conditions or catastrophic weather-related damage; |
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our production capabilities; |
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the consummation of financing, acquisition or disposition
transactions and the effect thereof on our business; |
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our ability to successfully integrate the operations we acquired
in the Nicewonder Acquisition with our existing operations, and
to successfully operate NCIs highway construction business; |
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our plans and objectives for future operations and expansion or
consolidation; |
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our relationships with, and other conditions affecting, our
customers; |
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timing of reductions in customer coal inventories; |
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long-term coal supply arrangements; |
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inherent risks of coal mining beyond our control; |
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environmental laws, including those directly affecting our coal
mining and production, and those affecting our customers
coal usage; |
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competition in coal markets; |
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railroad, barge, truck and other transportation performance and
costs; |
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availability of mining and processing equipment and parts; |
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our assumptions concerning economically recoverable coal reserve
estimates; |
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employee workforce factors; |
41
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regulatory and court decisions; |
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future legislation and changes in regulations, governmental
policies or taxes; |
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changes in post-retirement benefit obligations; |
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our liquidity, results of operations and financial
condition; and |
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other factors, including those discussed in Risk
Factors. |
MARKET AND INDUSTRY DATA AND FORECASTS
In this prospectus, we refer to information regarding the coal
industry in the United States and internationally that is
available from the American Iron and Steel Institute, the World
Coal Institute, the U.S. Department of Energy, the National
Energy Technology Laboratory, the U.S. Energy Information
Administration, Platts Research and Consulting, the
International Iron and Steel Institute, Bloomberg L.P., the
Bureau of Economic Analysis, Global Energy Advisors and BP
Statistical Review. These organizations are not affiliated with
us. They are not aware of and have not consented to being named
in this prospectus. We believe that this information is
reliable. In addition, in many cases we have made statements in
this prospectus regarding our industry and our position in the
industry based on our experience in the industry and our own
investigation of market conditions.
USE OF PROCEEDS
We will not receive any of the proceeds from the sale of common
stock in this offering.
DIVIDEND POLICY
We do not presently pay dividends on our common stock. We expect
to consider a policy of paying quarterly dividends beginning
sometime in 2006, initially of between $.02 and $.03 per
share, to the holders of our common stock. If adopted, we would
expect our board to commence and continue this dividend policy
for the foreseeable future subject to (1) our results of
operations and the amount of our surplus available to be
distributed, (2) dividend availability and restrictions
under our credit facility and indenture, (3) the dividend
rate being paid by comparable companies in the coal industry,
(4) our liquidity needs and financial condition,
(5) the level of cash investments we may make in connection
with potential future acquisitions and (6) other factors
that our board of directors may deem relevant. The terms of our
new credit facility and the indenture governing our senior notes
restrict our ability to pay dividends to our stockholders. See
Risk Factors Our ability to pay regular
dividends to our stockholders is subject to the discretion of
our board of directors and may be limited by our holding company
structure, the covenants in our debt instruments and applicable
provisions of Delaware law, and Risk
Factors The covenants in our credit facility and the
indenture governing our senior notes impose restrictions that
may limit our operating and financial flexibility.
PRICE RANGE OF OUR COMMON STOCK
Trading in our common stock commenced on the New York Stock
Exchange on February 15, 2005 under the symbol
ANR. The following table sets forth, for the periods
indicated, the high and low sales prices per share of our common
stock reported in the New York Stock Exchange consolidated tape.
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2005 |
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High | |
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Low | |
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First Quarter
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$ |
30.50 |
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$ |
21.65 |
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Second Quarter
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29.50 |
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22.00 |
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Third Quarter
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32.73 |
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23.83 |
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Fourth Quarter
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30.47 |
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18.70 |
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2006
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First Quarter (through January 5, 2006)
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19.82 |
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19.25 |
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42
CAPITALIZATION
The following table sets forth our cash and cash equivalents and
consolidated capitalization as of September 30, 2005 on an
actual basis and on a pro forma basis giving effect to the
Nicewonder Acquisition and the 2005 Financing, including our
repayment on November 2, 2005 of the $181.1 million
first installment of the promissory notes we issued to the
Nicewonder Coal Group sellers. You should read the information
in this table in conjunction with Unaudited Pro Forma
Financial Information and Managements
Discussion and Analysis of Financial Condition and Results of
Operations and our consolidated financial statements and
notes thereto, each included elsewhere in this prospectus.
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As of September 30, 2005 | |
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| |
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Actual | |
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Pro Forma | |
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(In millions) | |
Cash and cash equivalents
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$ |
0.1 |
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|
$ |
0.1 |
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Debt:
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Prior credit facility(1)
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81.0 |
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New credit facility(2)
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305.3 |
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10% senior notes due 2012
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175.0 |
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175.0 |
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Promissory notes(3)
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39.9 |
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Other debt(4)
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5.0 |
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5.0 |
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Total debt
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261.0 |
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|
|
525.2 |
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Stockholders equity:
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Preferred stock par value $0.01,
10,000,000 shares authorized, no shares issued
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Common stock par value $0.01,
100,000,000 shares authorized, 62,212,580 shares
issued and 64,392,813 shares issued pro forma(5)
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0.6 |
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|
0.6 |
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Additional paid-in-capital
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|
|
146.4 |
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|
|
199.6 |
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Unearned Stock-Based Compensation
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|
|
(18.6 |
) |
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|
(18.6 |
) |
Retained Earnings
|
|
|
6.1 |
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|
|
4.6 |
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|
|
|
|
|
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|
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Total stockholders equity
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|
|
134.5 |
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|
|
186.2 |
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Total capitalization
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|
$ |
395.5 |
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|
$ |
711.4 |
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(1) |
Our prior credit facility provided for a $50.0 million
funded letter of credit facility and a revolving credit facility
of up to $125.0 million (under which $50.0 million was
available for additional letters of credit). As of
September 30, 2005, we had $81.0 million of
indebtedness and an additional $53.0 million of letters of
credit outstanding under our prior credit facility. |
|
(2) |
In connection with the closing of the Nicewonder Acquisition, we
consummated the 2005 Financing and terminated our prior credit
facility. As of September 30, 2005, on a pro forma basis
giving effect to the Nicewonder Acquisition and 2005 Financing,
including our repayment on November 2, 2005 of the
$181.1 million first installment of the promissory notes we
issued to the Nicewonder Coal Group sellers, we would have had
approximately $305.3 million of indebtedness and an
additional $65.5 million of letters of credit outstanding
under our new credit facility, resulting in availability under
the new revolving credit facility of approximately
$154.2 million. See Description of
Indebtedness Credit Facility. |
|
(3) |
Includes promissory installment notes issued to the sellers
pursuant to the Nicewonder Acquisition by one of our indirect,
wholly owned subsidiaries, which are due on January 15,
2006. The first installment of the promissory notes, in the
principal amount of $181.1 million, was paid on
November 2, 2005. |
|
(4) |
Includes $1.6 million of capital lease obligations
extending through March 2009, $0.6 million principal amount
in variable rate term notes maturing in April 2006 that we
incurred in connection with equipment financing and
$2.8 million payable to an insurance premium finance
company in installments of approximately $1.4 million per
month through November of 2005. |
|
(5) |
As part of the Nicewonder Acquisition, we issued 2,180,233
shares of our common stock valued at approximately
$53.2 million for accounting purposes. For this purpose,
the value of the common stock issued was based on the average
closing prices of our common stock for the five trading days
surrounding October 20, 2005, the date the number of shares
to be issued under the terms of the acquisition agreement became
fixed without subsequent revision. |
43
UNAUDITED PRO FORMA FINANCIAL INFORMATION
The following unaudited pro forma financial information has been
derived by application of pro forma adjustments to the audited
combined financial statements of ANR Fund IX Holdings, L.P.
and Alpha NR Holding, Inc. and subsidiaries and to the unaudited
interim consolidated condensed financial statements of Alpha
Natural Resources, Inc. and subsidiaries included elsewhere in
this prospectus. The unaudited pro forma condensed balance sheet
data as of September 30, 2005, give effect to the
Nicewonder Acquisition and the 2005 Financing, as if each had
occurred on September 30, 2005. The unaudited pro forma
condensed statement of operations data for the year ended
December 31, 2004 and the nine months ended
September 30, 2005, give effect to the following events, in
each case as if they had occurred on January 1, 2004:
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the issuance by Alpha Natural Resources, LLC and its
wholly-owned subsidiary, Alpha Natural Resources Capital Corp.
on May 18, 2004, of $175.0 million principal amount of
10% senior notes due 2012, and our entry into a
$175.0 million credit facility on May 28, 2004
(together referred to as the 2004 Financings); |
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|
|
the Internal Restructuring described in Note (1) to the
audited combined financial statements of ANR Fund IX
Holdings, L.P. and Alpha NR Holding, Inc. and subsidiaries
included elsewhere in this prospectus; |
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the IPO; |
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the Nicewonder Acquisition; and |
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|
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the 2005 Financing, including our use of a portion of the
proceeds therefrom to repay in full indebtedness outstanding
under our prior credit facility and to pay the first installment
of the promissory notes we issued to the Nicewonder Coal Group
sellers. |
The pro forma adjustments, which are based upon available
information and upon assumptions that management believes to be
reasonable, are described in the accompanying notes.
The unaudited pro forma consolidated financial information is
for informational purposes only, should not be considered
indicative of actual results that would have been achieved had
the transactions actually been consummated on the dates
indicated and do not purport to be indicative of results of
operations or financial position as of any future date or for
any future period. The unaudited pro forma consolidated
financial information should be read in conjunction with
Selected Historical Financial Data,
Managements Discussion and Analysis of Financial
Condition and Results of Operations, and our financial
statements and the related notes included elsewhere in this
prospectus.
44
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
UNAUDITED PRO FORMA CONDENSED CONSOLIDATED BALANCE SHEET
DATA
September 30, 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nicewonder | |
|
2005 | |
|
|
|
|
Historical(1) | |
|
Acquisition | |
|
Financing | |
|
Pro Forma | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share and per share amounts) | |
ASSETS |
Current assets
|
|
$ |
280,095 |
|
|
$ |
21,526 |
(2) |
|
$ |
|
|
|
$ |
301,621 |
|
Property, plant and equipment, net
|
|
|
267,481 |
|
|
|
280,094 |
(2) |
|
|
|
|
|
|
547,575 |
|
Goodwill
|
|
|
18,641 |
|
|
|
6,885 |
(2) |
|
|
|
|
|
|
25,526 |
|
Other intangibles, net
|
|
|
560 |
|
|
|
26,106 |
(2) |
|
|
|
|
|
|
26,666 |
|
Deferred income taxes
|
|
|
19,616 |
|
|
|
|
(9) |
|
|
|
|
|
|
19,616 |
|
Other assets
|
|
|
35,705 |
|
|
|
|
|
|
|
8,000 |
(7) |
|
|
42,205 |
|
|
|
|
|
|
|
|
|
|
|
|
(1,500 |
)(7) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
622,098 |
|
|
$ |
334,611 |
|
|
$ |
6,500 |
|
|
$ |
963,209 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
Current liabilities
|
|
$ |
154,495 |
|
|
$ |
11,526 |
(2) |
|
$ |
|
|
|
$ |
211,721 |
|
|
|
|
|
|
|
|
5,800 |
(3) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
221,000 |
(5) |
|
|
(181,100 |
)(8) |
|
|
|
|
Long-term debt, net of current portion
|
|
|
257,163 |
|
|
|
35,200 |
(4) |
|
|
189,100 |
(8) |
|
|
481,463 |
|
Workers compensation benefits
|
|
|
5,113 |
|
|
|
|
|
|
|
|
|
|
|
5,113 |
|
Postretirement medical benefits
|
|
|
22,226 |
|
|
|
|
|
|
|
|
|
|
|
22,226 |
|
Asset retirement obligation
|
|
|
34,284 |
|
|
|
7,900 |
(2) |
|
|
|
|
|
|
42,184 |
|
Deferred gains on sale of property interests
|
|
|
5,166 |
|
|
|
|
|
|
|
|
|
|
|
5,166 |
|
Deferred income taxes
|
|
|
|
|
|
|
|
(9) |
|
|
|
|
|
|
|
|
Other liabilities
|
|
|
9,178 |
|
|
|
|
|
|
|
|
|
|
|
9,178 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
487,625 |
|
|
|
281,426 |
|
|
|
8,000 |
|
|
|
777,051 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock par value $0.01,
10,000,000 shares authorized, none issued
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock par value $0.01,
100,000,000 shares authorized, 62,212,580 shares
issued and outstanding, 64,392,813 shares issued and
outstanding pro forma
|
|
|
622 |
|
|
|
22 |
(6) |
|
|
|
|
|
|
644 |
|
|
Additional paid-in capital
|
|
|
146,372 |
|
|
|
53,163 |
(6) |
|
|
|
|
|
|
199,535 |
|
|
Unearned stock-based compensation
|
|
|
(18,623 |
) |
|
|
|
|
|
|
|
|
|
|
(18,623 |
) |
|
Retained earnings
|
|
|
6,102 |
|
|
|
|
|
|
|
(1,500 |
)(7) |
|
|
4,602 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
134,473 |
|
|
|
53,815 |
|
|
|
(1,500 |
) |
|
|
186,158 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$ |
622,098 |
|
|
$ |
334,611 |
|
|
$ |
6,500 |
|
|
|
963,209 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Reflects the consolidated condensed balance sheet of Alpha
Natural Resources, Inc. and subsidiaries as of
September 30, 2005. |
|
(2) |
Reflects the estimated fair value of the net assets acquired
from The Combined Entities of The Nicewonder Coal Group as shown
in the table below. The Nicewonder Coal Group had equipment
financing indebtedness of $41.3 million as of
September 30, 2005, all of which was repaid prior to the
closing of the Nicewonder Acquisition. The aggregate purchase
price of the Nicewonder Acquisition was $315.2 million,
consisting of cash at closing in the amount of
$35.2 million, a cash tax payment |
45
|
|
|
of $1.9 million to be made to the sellers in April 2006,
estimated transaction costs of $3.9 million, installment
promissory notes issued to the sellers in the aggregate
principal amount of $221.0 million, $181.1 million of
which was paid on November 2, 2005, with the remaining
$39.9 million due on January 15, 2006, and
2,180,233 shares of our common stock valued at
approximately $53.2 million for accounting purposes. |
|
|
|
|
|
|
|
|
(In thousands) | |
Current assets
|
|
$ |
21,526 |
|
Property, plant and equipment
|
|
|
280,094 |
|
Other intangibles
|
|
|
26,106 |
|
Goodwill
|
|
|
6,885 |
|
|
|
|
|
|
Total assets acquired
|
|
|
334,611 |
|
|
|
|
|
Current liabilities
|
|
|
11,526 |
|
Asset retirement obligation
|
|
|
7,900 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
19,426 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
315,185 |
|
|
|
|
|
|
|
|
|
|
The purchase price allocation is based on preliminary estimates
of the fair values of the assets acquired and liabilities
assumed, and we have initiated a study to evaluate the fair
values of the assets and liabilities. Fair market value
adjustments reflected in the pro forma financial statements may
be subject to revisions and adjustments pending finalization of
the evaluation. |
|
(3) |
|
Reflects a cash tax payment of $1.9 million to be made to
the sellers in April 2006 and estimated transaction costs of
$3.9 million. |
|
(4) |
|
Reflects borrowings under our new credit facility revolver to
pay the $35.2 million of cash paid to the sellers at the
closing of the Nicewonder Acquisition. |
|
(5) |
|
Reflects the issuance of notes payable to the Nicewonder Coal
Group sellers. |
|
(6) |
|
Reflects the issuance of 2,180,233 shares to the Nicewonder Coal
Group sellers at a value of $24.39 per share. For this
purpose, the value was based on the average closing prices of
our common stock for the five trading days surrounding
October 20, 2005, the date the number of shares to be
issued under the terms of the acquisition agreement became fixed
without subsequent revision. |
|
(7) |
|
Reflects $8.0 million of estimated deferred financing costs
associated with the 2005 Financings and the write-off of
$1.5 million of the unamortized balance of the deferred
financing costs related to our existing revolver. |
|
(8) |
|
Reflects the issuance of the $250.0 million seven-year term
loan, the draw on our new revolver of $55.3 million, the
repayment of the first installment of the seller notes in the
amount of $181.1 million, the repayment of
$81.0 million of our prior revolver, and the payment of
$35.2 million due to the sellers at the closing of the
Nicewonder Acquisition. |
|
(9) |
|
The pro forma balance sheet reflects a pro forma adjustment to
record a deferred tax liability of $22.0 million due to the
excess of financial accounting basis for the assets of the
acquired companies over their tax basis. The pro forma balance
sheet also reflects an adjustment to reverse previously recorded
valuation allowance of $22.0 million due to changes in the
estimate of the future realizability of our existing deferred
tax assets, which offsets the net deferred tax liability
recorded on the acquisition. The change in the estimate of the
future realizability of the existing deferred tax assets is
based upon the expectation of future taxable income from the
reversal of the acquired deferred tax liability. We are
completing a comprehensive analysis of the recoverability of our
deferred tax assets, and such analysis may result in adjustments
to the valuation allowance with an offsetting adjustment to
goodwill. |
46
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
UNAUDITED PRO FORMA STATEMENT OF OPERATIONS DATA
For the year ended December 31, 2004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
Internal | |
|
|
|
Nicewonder | |
|
2005 | |
|
|
|
|
|
|
Financings | |
|
Restructuring | |
|
Subtotal | |
|
Acquisition | |
|
Financing | |
|
Total | |
|
|
Historical | |
|
Pro Forma | |
|
Pro Forma | |
|
Pro Forma | |
|
Pro Forma | |
|
Pro Forma | |
|
Pro Forma | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(1) | |
|
(2) | |
|
(3) | |
|
|
|
(4) | |
|
(5) | |
|
|
|
|
(In thousands, except share and per share amounts) | |
Total revenues
|
|
$ |
1,252,702 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
1,252,702 |
|
|
$ |
144,613 |
|
|
$ |
|
|
|
$ |
1,397,315 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating costs (exclusive of items shown separately below(6)
|
|
|
1,084,453 |
|
|
|
|
|
|
|
|
|
|
|
1,084,453 |
|
|
|
104,421 |
|
|
|
|
|
|
|
1,188,874 |
|
|
Depreciation, depletion and amortization
|
|
|
55,261 |
|
|
|
|
|
|
|
|
|
|
|
55,261 |
|
|
|
51,000 |
|
|
|
|
|
|
|
106,261 |
|
|
Selling, general and administrative expenses
|
|
|
43,881 |
|
|
|
|
|
|
|
|
|
|
|
43,881 |
|
|
|
2,973 |
|
|
|
|
|
|
|
46,854 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
1,183,595 |
|
|
|
|
|
|
|
|
|
|
|
1,183,595 |
|
|
|
158,394 |
|
|
|
|
|
|
|
1,341,989 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
69,107 |
|
|
|
|
|
|
|
|
|
|
|
69,107 |
|
|
|
(13,781 |
) |
|
|
|
|
|
|
55,326 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(20,041 |
) |
|
|
(2,697 |
) |
|
|
|
|
|
|
(22,738 |
) |
|
|
(1,351 |
) |
|
|
(13,808 |
) |
|
|
(37,897 |
) |
|
Interest income
|
|
|
531 |
|
|
|
|
|
|
|
|
|
|
|
531 |
|
|
|
161 |
|
|
|
|
|
|
|
692 |
|
|
Miscellaneous income (expense), net
|
|
|
722 |
|
|
|
|
|
|
|
|
|
|
|
722 |
|
|
|
(278 |
) |
|
|
|
|
|
|
444 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(18,788 |
) |
|
|
(2,697 |
) |
|
|
|
|
|
|
(21,485 |
) |
|
|
(1,468 |
) |
|
|
(13,808 |
) |
|
|
(36,761 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations before income taxes and
minority interest
|
|
|
50,319 |
|
|
|
(2,697 |
) |
|
|
|
|
|
|
47,622 |
|
|
|
(15,249 |
) |
|
|
(13,808 |
) |
|
|
18,565 |
|
Income tax expense (benefit)
|
|
|
5,150 |
|
|
|
(1,025 |
) |
|
|
9,806 |
|
|
|
13,931 |
|
|
|
(5,795 |
) |
|
|
(5,247 |
) |
|
|
2,889 |
|
Minority interest
|
|
|
22,781 |
|
|
|
|
|
|
|
(22,781 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
$ |
22,388 |
|
|
|
(1,672 |
) |
|
|
12,975 |
|
|
|
33,691 |
|
|
|
(9,454 |
) |
|
|
(8,561 |
) |
|
|
15,676 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.55 |
(7) |
|
|
|
|
|
|
|
|
|
$ |
0.25 |
(8) |
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.54 |
(7) |
|
|
|
|
|
|
|
|
|
$ |
0.24 |
(8) |
Weighted average shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
60,867,650 |
(7) |
|
|
|
|
|
|
|
|
|
|
63,047,883 |
(8) |
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
62,409,586 |
(7) |
|
|
|
|
|
|
|
|
|
|
64,589,819 |
(8) |
|
|
(1) |
Reflects the combined results of operations of ANR Fund IX
Holdings, L.P. and Alpha NR Holdings, Inc. and subsidiaries for
the year ended December 31, 2004. |
|
(2) |
Represents pro forma interest expense, net of income taxes at
the statutory rate of 38%, resulting from the 2004 Financings as
shown in the table below (In thousands): |
|
|
|
|
|
|
|
Notes payable
|
|
$ |
228 |
|
|
Reflects interest at a fixed rate of 3.55% on an average balance
of $7.2 million. |
Equipment financing
|
|
|
101 |
|
|
Reflects pro forma interest expense at a fixed rate of 4.79% on
an estimated average balance of $2.1 million. |
Senior notes
|
|
|
17,500 |
|
|
Reflects pro forma interest expense at a fixed rate of 10% on
our senior notes. |
47
|
|
|
|
|
|
|
|
Funded revolver
|
|
|
1,111 |
|
|
Reflects pro forma interest at LIBOR of 1.52% plus 2.75% on an
estimated average balance of $26.0 million. |
Letter of credit fees
|
|
|
1,563 |
|
|
Reflects fees at the fixed rate of 3.1% on $50.0 million
letters of credit outstanding under our funded letter of credit
facility. |
Commitment fees
|
|
|
495 |
|
|
Reflects commitment fees at 0.50% on an estimated
$99.0 million average available balance. |
|
|
|
|
|
|
|
Total cash interest expense
|
|
|
20,998 |
|
|
|
Amortization of deferred loan costs
|
|
|
1,740 |
|
|
Reflects deferred financing costs of $11.7 million
amortized over approximately 7 years. |
|
|
|
|
|
|
|
Total pro forma interest expense
|
|
|
22,738 |
|
|
|
Less: historical interest expense
|
|
|
(20,041 |
) |
|
|
|
|
|
|
|
|
|
Adjustment to interest expense
|
|
$ |
2,697 |
|
|
|
|
|
|
|
|
|
|
|
(3) |
Reflects the elimination of minority interest and related income
tax effects as a result of the Internal Restructuring. |
|
(4) |
Represents the pro forma results of operations of The Nicewonder
Coal Group for the year ended December 31, 2004 as if the
Nicewonder Acquisition had occurred on January 1, 2004 (In
thousands): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nicewonder | |
|
|
|
Nicewonder | |
|
|
Coal Group | |
|
Pro Forma | |
|
Coal Group | |
|
|
Historical(a) | |
|
Adjustments | |
|
Pro Forma | |
|
|
| |
|
| |
|
| |
Total revenues
|
|
$ |
144,613 |
|
|
$ |
|
|
|
$ |
144,613 |
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating costs (exclusive of items shown separately below)
|
|
|
103,958 |
|
|
|
463 |
(b) |
|
|
104,421 |
|
|
Depreciation, depletion and amortization
|
|
|
11,336 |
|
|
|
39,664 |
(c) |
|
|
51,000 |
|
|
Selling, general and administrative expenses
|
|
|
2,973 |
|
|
|
|
|
|
|
2,973 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
118,267 |
|
|
|
40,127 |
|
|
|
158,394 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
26,346 |
|
|
|
(40,127 |
) |
|
|
(13,781 |
) |
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,351 |
) |
|
|
|
|
|
|
(1,351 |
) |
|
Interest income
|
|
|
161 |
|
|
|
|
|
|
|
161 |
|
|
Miscellaneous income (expense), net
|
|
|
(278 |
) |
|
|
|
|
|
|
(278 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(1,468 |
) |
|
|
|
|
|
|
(1,468 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations before income taxes
|
|
|
24,878 |
|
|
|
(40,127 |
) |
|
|
(15,249 |
) |
Income tax expense (benefit)
|
|
|
|
|
|
|
(5,795 |
)(d) |
|
|
(5,795 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
$ |
24,878 |
|
|
$ |
(34,332 |
) |
|
$ |
(9,454 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) |
|
Reflects the results of operations of The Combined Entities of
The Nicewonder Coal Group for the year ended December 31,
2004. |
(b) |
|
Reflects the estimated cost of providing retiree medical
coverage to the production employees under Alphas employee
benefit plan. |
(c) |
|
Reflects the additional charge for depreciation, depletion and
amortization arising from purchase accounting. |
(d) |
|
Reflects the benefit of income taxes computed at the combined
federal and state statutory rate of 38% on pro forma net loss of
$15.2 million. The Combined Entities of the Nicewonder Coal
Group were all pass-through entities for income tax purposes
before the acquisition. Accordingly, the pro forma presentation
computes income taxes on the pro forma loss before income taxes. |
48
|
|
(5) |
Represents pro forma interest expense, net of income taxes at
the statutory rate of 38%, resulting from the 2005 Financing as
shown in the table below (In thousands): |
|
|
|
|
|
|
|
|
Notes payable
|
|
$ |
228 |
|
|
Reflects interest on an average balance of $7.2 million. |
Equipment financing
|
|
|
101 |
|
|
Reflects interest on an estimated average balance of
$2.0 million. |
Senior notes
|
|
|
17,500 |
|
|
Reflects interest at a fixed rate of 10% on our senior notes. |
Funded revolver
|
|
|
615 |
|
|
Reflects interest at a variable rate of 6.15% on an estimated
balance of $10.0 million. |
Term loan
|
|
|
14,250 |
|
|
Reflects interest at a variable rate of 5.7% on a balance of
$250.0 million. |
Letter of credit fees
|
|
|
1,860 |
|
|
Reflects fees at the fixed rate of 3.1% on an estimated
$60.0 million stated amount of letters of credit
outstanding. |
Commitment fees
|
|
|
1,025 |
|
|
Reflects commitment fees at the fixed rate of 0.50% on a
estimated average available balance of $205.0 million. |
|
|
|
|
|
|
|
Total cash interest expense
|
|
|
35,579 |
|
|
|
Amortization of deferred loan costs
|
|
|
2,318 |
|
|
|
|
|
|
|
|
|
|
Total pro forma interest
|
|
|
37,897 |
|
|
|
Less: historical interest expense
|
|
|
(24,089 |
) |
|
|
|
|
|
|
|
|
|
Adjustment to interest expense
|
|
$ |
13,808 |
|
|
|
|
|
|
|
|
|
|
|
(6) |
Operating expenses include cost of coal sales, freight and
handling costs and the costs of other revenues. |
|
(7) |
Earnings per share and the related weighted shares outstanding
reflect the additional pro forma effect of our issuance of
33,925,000 shares of our common stock in our IPO on
February 18, 2005 as if that occurred at the beginning of
2004. See footnote (2) in Prospectus
Summary Alpha Summary Historical and Pro Forma
Financial Data for an explanation of the calculation of
our earnings per share and the related weighted shares
outstanding. |
|
(8) |
Earnings per share and the related weighted shares outstanding
reflect the additional pro forma, as adjusted effect of our
issuance of 33,925,000 shares of our common stock in our IPO on
February 18, 2005 as if that occurred at the beginning of
2004. See footnote (2) in Prospectus
Summary Alpha Summary Historical and Pro Forma
Financial Data for an explanation of the calculation of
our earnings per share and the related weighted shares
outstanding. |
49
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
UNAUDITED PRO FORMA STATEMENT OF OPERATIONS DATA
For the nine months ended September 30, 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nicewonder | |
|
2005 | |
|
|
|
|
|
|
Internal | |
|
|
|
Acquisition | |
|
Financing | |
|
|
|
|
Historical | |
|
Restructuring | |
|
Subtotal | |
|
Pro Forma | |
|
Pro Forma | |
|
Total | |
|
|
(1) | |
|
(2) | |
|
Pro Forma | |
|
(3) | |
|
(4) | |
|
Pro Forma | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share and per share amounts) | |
Total revenues
|
|
$ |
1,127,480 |
|
|
|
|
|
|
$ |
1,127,480 |
|
|
$ |
156,855 |
|
|
$ |
|
|
|
$ |
1,284,335 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating costs (exclusive of items shown separately below)(5)
|
|
|
961,276 |
|
|
|
|
|
|
|
961,276 |
|
|
|
102,680 |
|
|
|
|
|
|
|
1,063,956 |
|
|
Depreciation, depletion and amortization
|
|
|
45,521 |
|
|
|
|
|
|
|
45,521 |
|
|
|
38,260 |
|
|
|
|
|
|
|
83,781 |
|
|
Selling, general and administrative expenses
|
|
|
74,924 |
|
|
|
|
|
|
|
74,924 |
|
|
|
2,668 |
|
|
|
|
|
|
|
77,592 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
1,081,721 |
|
|
|
|
|
|
|
1,081,721 |
|
|
|
143,608 |
|
|
|
|
|
|
|
1,225,329 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
45,759 |
|
|
|
|
|
|
|
45,759 |
|
|
|
13,247 |
|
|
|
|
|
|
|
59,006 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(19,400 |
) |
|
|
|
|
|
|
(19,400 |
) |
|
|
(1,593 |
) |
|
|
(9,867 |
) |
|
|
(30,860 |
) |
|
Interest income
|
|
|
675 |
|
|
|
|
|
|
|
675 |
|
|
|
302 |
|
|
|
|
|
|
|
977 |
|
|
Miscellaneous income, net
|
|
|
40 |
|
|
|
|
|
|
|
40 |
|
|
|
92 |
|
|
|
|
|
|
|
132 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(18,685 |
) |
|
|
|
|
|
|
(18,685 |
) |
|
|
(1,199 |
) |
|
|
(9,867 |
) |
|
|
(29,751 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations before income taxes and
minority interest
|
|
|
27,074 |
|
|
|
|
|
|
|
27,074 |
|
|
|
12,048 |
|
|
|
(9,867 |
) |
|
|
29,255 |
|
Income tax expense (benefit)
|
|
|
15,141 |
|
|
|
778 |
|
|
|
15,919 |
|
|
|
4,578 |
|
|
|
(3,749 |
) |
|
|
16,748 |
|
Minority interest
|
|
|
2,918 |
|
|
|
(2,918 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
9,015 |
|
|
$ |
2,140 |
|
|
$ |
11,155 |
|
|
$ |
7,470 |
|
|
$ |
(6,118 |
) |
|
$ |
12,507 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income from continuing operations per share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.17 |
(6) |
|
|
|
|
|
$ |
0.18 |
(6) |
|
|
|
|
|
|
|
|
|
$ |
0.20 |
(7) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
53,184,066 |
(6) |
|
|
|
|
|
|
61,092,832 |
(6) |
|
|
|
|
|
|
|
|
|
|
63,273,065 |
(7) |
|
Diluted
|
|
|
53,566,469 |
(6) |
|
|
|
|
|
|
61,677,221 |
(6) |
|
|
|
|
|
|
|
|
|
|
63,857,454 |
(7) |
|
|
(1) |
Reflects the consolidated results of operations of Alpha Natural
Resources, Inc. and subsidiaries for the nine months ended
September 30, 2005. |
50
|
|
(2) |
Reflects the elimination of minority interest and related income
tax effects as a result of the Internal Restructuring. |
|
(3) |
Represents the pro forma results of operations of the Nicewonder
Coal Group for the nine months ended September 30, 2005, as
if the Nicewonder Acquisition had occurred on January 1,
2004 (in thousands): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Historical | |
|
Pro forma | |
|
|
|
|
(a) | |
|
Adjustments | |
|
Pro forma | |
|
|
| |
|
| |
|
| |
Total revenues
|
|
$ |
156,855 |
|
|
$ |
|
|
|
$ |
156,855 |
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating costs (exclusive of items shown separately below)
|
|
|
102,333 |
|
|
|
347 |
(b) |
|
|
102,680 |
|
|
Depreciation, depletion and amortization
|
|
|
10,340 |
|
|
|
27,920 |
(c) |
|
|
38,260 |
|
|
Selling, general and administrative expenses
|
|
|
2,668 |
|
|
|
|
|
|
|
2,668 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
115,341 |
|
|
|
28,267 |
|
|
|
143,608 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
41,514 |
|
|
|
(28,267 |
) |
|
|
13,247 |
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,593 |
) |
|
|
|
|
|
|
(1,593 |
) |
|
Interest income
|
|
|
302 |
|
|
|
|
|
|
|
302 |
|
|
Miscellaneous income, net
|
|
|
92 |
|
|
|
|
|
|
|
92 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(1,199 |
) |
|
|
|
|
|
|
(1,199 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations before income taxes
|
|
|
40,315 |
|
|
|
(28,267 |
) |
|
|
12,048 |
|
Income tax expense
|
|
|
|
|
|
|
4,578 |
(d) |
|
|
4,578 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
40,315 |
|
|
$ |
(32,845 |
) |
|
$ |
7,470 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) |
|
Reflects the results of operations of The Combined Entities of
The Nicewonder Coal Group for the nine months ended
September 30, 2005 |
|
(b) |
|
Reflects the estimated cost of providing retiree medical
coverage to the production employees under Alphas employee
benefit plan. |
|
(c) |
|
Reflects the additional charge for depreciation, depletion and
amortization arising from purchase accounting. |
|
(d) |
|
The Combined Entities of The Nicewonder Coal Group were all
pass-through entities for income tax purposes before the
acquisition. Accordingly, the pro forma presentation reflects
income taxes computed at the combined federal and state
statutory rate of 38% on pro forma pre-tax income. |
51
|
|
|
(4) |
|
Represents pro forma interest expense for the nine months ended
September 30, 2005, net of income taxes at the statutory
rate of 38%, resulting from our 2005 Refinancing as shown in the
table below (in thousands): |
|
|
|
|
|
|
|
|
Notes payable
|
|
$ |
256 |
|
|
Reflects interest on an average balance of $9.0 million. |
Equipment financing
|
|
|
215 |
|
|
Reflects interest on an average balance of $2.8 million. |
Senior notes
|
|
|
13,375 |
|
|
Reflects interest expense at a fixed rate of 10% on our senior
notes. |
Funded revolver
|
|
|
2,491 |
|
|
Reflects interest at a variable rate of 6.15% on an estimated
balance of $54.0 million. |
Term loan
|
|
|
10,688 |
|
|
Reflects interest at a variable rate of 5.7% on a balance of
$250.0 million. |
Letter of credit fees
|
|
|
1,511 |
|
|
Reflects fees at the fixed rate of 3.1% on an estimated balance
of $65.0 million. |
Commitment fees
|
|
|
585 |
|
|
Reflects fees at the fixed rate of .5% on an estimated
$156.0 million average available balance. |
|
|
|
|
|
|
|
Total cash interest expense
|
|
|
29,121 |
|
|
|
Amortization of deferred loan costs
|
|
|
1,739 |
|
|
|
|
|
|
|
|
|
|
Total pro forma interest
|
|
|
30,860 |
|
|
|
Less: interest as recorded
|
|
|
(20,993 |
) |
|
|
|
|
|
|
|
|
|
Adjustment to interest expense
|
|
$ |
9,867 |
|
|
|
|
|
|
|
|
|
|
|
|
(5) |
|
Operating expenses include cost of coal sales, freight and
handling costs and the costs of other revenues. |
|
(6) |
|
Earnings per share and the related weighted shares outstanding
reflect the additional pro forma effect of our issuance of
33,925,000 shares of our common stock in our IPO on
February 18, 2005 as if that occurred at the beginning of
2004. See footnote (2) in Prospectus
Summary Alpha Summary Historical and Pro Forma
Financial Data for an explanation of the calculation of
our earnings per share and the related weighted shares
outstanding. |
|
(7) |
|
Earnings per share and the related weighted shares outstanding
reflect the additional pro forma, as adjusted effect of our
issuance of 33,925,000 shares of our common stock in our IPO on
February 18, 2005 as if that occurred at the beginning of
2004. See footnote (2) in Prospectus
Summary Alpha Summary Historical and Pro Forma
Financial Data for an explanation of the calculation of
our earnings per share and the related weighted shares
outstanding. |
52
SELECTED HISTORICAL FINANCIAL DATA
The following table presents selected financial and other data
about us and our Predecessor for the most recent five fiscal
years and the first six months of 2005 and 2004. The selected
historical financial data as of December 31, 2004 and 2003,
for the years ended December 31, 2004 and 2003, and for the
period from December 14, 2002 to December 31, 2002,
have been derived from the combined financial statements of ANR
Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
subsidiaries and the related notes, included elsewhere in this
prospectus, which have been audited by KPMG, an independent
registered public accounting firm. The selected historical
financial data as of December 31, 2002 have been derived
from the audited combined balance sheet of ANR Fund IX
Holdings, L.P. and Alpha NR Holding, Inc. and subsidiaries not
included in this prospectus. The selected historical financial
data for the period from January 1, 2002 through
December 13, 2002 (the Predecessor Period) have
been derived from our Predecessors combined financial
statements included elsewhere in this prospectus, which have
been audited by KPMG. The selected historical financial data as
of December 31, 2001 and 2000, and for the years ended
December 31, 2001 and 2000 have been derived from our
Predecessors audited combined financial statements not
included in this prospectus. The selected historical financial
data as of September 30, 2005 and for the nine months ended
September 30, 2005 and 2004, have been derived from the
unaudited consolidated condensed interim financial statements of
Alpha NR Holding, Inc. and subsidiaries, and the related notes,
included elsewhere in this prospectus. Our historical financial
statements have been restated to report the disposition of NKC
as discontinued operations. You should read the following table
in conjunction with the financial statements, the related notes
to those financial statements, and Managements
Discussion and Analysis of Financial Condition and Results of
Operations included elsewhere in this prospectus.
53
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
|
|
|
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|
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|
|
|
|
|
|
Alpha Natural | |
|
|
|
|
ANR Fund IX Holdings, L.P. and Alpha NR Holding, Inc. | |
|
Resources, Inc. and | |
|
|
Predecessor | |
|
and Subsidiaries | |
|
Subsidiaries | |
|
|
| |
|
| |
|
| |
|
|
Years Ended | |
|
January 1, | |
|
December 14, | |
|
|
|
Nine Months | |
|
Nine Months | |
|
|
December 31, | |
|
2002 to | |
|
2002 to | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
| |
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2000 | |
|
2001 | |
|
2002 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per share amounts) | |
Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
226,653 |
|
|
$ |
227,237 |
|
|
$ |
154,715 |
|
|
$ |
6,260 |
|
|
$ |
694,591 |
|
|
$ |
1,079,733 |
|
|
$ |
801,021 |
|
|
$ |
982,383 |
|
|
Freight and handling revenues
|
|
|
25,470 |
|
|
|
25,808 |
|
|
|
17,001 |
|
|
|
1,009 |
|
|
|
73,800 |
|
|
|
141,100 |
|
|
|
102,846 |
|
|
|
126,650 |
|
|
Other revenues
|
|
|
5,601 |
|
|
|
8,472 |
|
|
|
6,031 |
|
|
|
101 |
|
|
|
13,458 |
|
|
|
31,869 |
|
|
|
20,440 |
|
|
|
18,447 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
257,724 |
|
|
|
261,517 |
|
|
|
177,747 |
|
|
|
7,370 |
|
|
|
781,849 |
|
|
|
1,252,702 |
|
|
|
924,307 |
|
|
|
1,127,480 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales (exclusive of items shown separately below)
|
|
|
224,230 |
|
|
|
219,545 |
|
|
|
158,924 |
|
|
|
6,268 |
|
|
|
626,265 |
|
|
|
920,359 |
|
|
|
668,887 |
|
|
|
818,299 |
|
|
Freight and handling costs
|
|
|
25,470 |
|
|
|
25,808 |
|
|
|
17,001 |
|
|
|
1,009 |
|
|
|
73,800 |
|
|
|
141,100 |
|
|
|
102,846 |
|
|
|
126,650 |
|
|
Cost of other revenues
|
|
|
4,721 |
|
|
|
8,156 |
|
|
|
7,973 |
|
|
|
120 |
|
|
|
12,488 |
|
|
|
22,994 |
|
|
|
14,942 |
|
|
|
16,327 |
|
|
Depreciation, depletion and amortization
|
|
|
7,890 |
|
|
|
7,866 |
|
|
|
6,814 |
|
|
|
274 |
|
|
|
35,385 |
|
|
|
55,261 |
|
|
|
38,883 |
|
|
|
45,521 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
8,543 |
|
|
|
9,370 |
|
|
|
8,797 |
|
|
|
471 |
|
|
|
21,926 |
|
|
|
43,881 |
|
|
|
35,786 |
|
|
|
74,924 |
|
|
Costs to exit business
|
|
|
26,937 |
|
|
|
3,500 |
|
|
|
25,274 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
297,791 |
|
|
|
274,245 |
|
|
|
224,783 |
|
|
|
8,142 |
|
|
|
769,864 |
|
|
|
1,183,595 |
|
|
|
861,344 |
|
|
|
1,081,721 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refund of federal black lung excise tax
|
|
|
|
|
|
|
16,213 |
|
|
|
2,049 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other operating income, net
|
|
|
57 |
|
|
|
94 |
|
|
|
1,430 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
(40,010 |
) |
|
|
3,579 |
|
|
|
(43,557 |
) |
|
|
(772 |
) |
|
|
11,985 |
|
|
|
69,107 |
|
|
|
62,963 |
|
|
|
45,759 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
|
|
|
|
|
|
|
|
(35 |
) |
|
|
(203 |
) |
|
|
(7,848 |
) |
|
|
(20,041 |
) |
|
|
(14,497 |
) |
|
|
(19,400 |
) |
|
Interest income
|
|
|
2,263 |
|
|
|
1,993 |
|
|
|
2,072 |
|
|
|
6 |
|
|
|
103 |
|
|
|
531 |
|
|
|
331 |
|
|
|
675 |
|
|
Miscellaneous income
|
|
|
4,215 |
|
|
|
1,250 |
|
|
|
|
|
|
|
|
|
|
|
574 |
|
|
|
722 |
|
|
|
517 |
|
|
|
40 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
6,478 |
|
|
|
3,243 |
|
|
|
2,037 |
|
|
|
(197 |
) |
|
|
(7,171 |
) |
|
|
(18,788 |
) |
|
|
(13,649 |
) |
|
|
(18,685 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income taxes and minority interest
|
|
|
(33,532 |
) |
|
|
6,822 |
|
|
|
(41,520 |
) |
|
|
(969 |
) |
|
|
4,814 |
|
|
|
50,319 |
|
|
|
49,314 |
|
|
|
27,074 |
|
Income tax expense (benefit)
|
|
|
(13,545 |
) |
|
|
(1,497 |
) |
|
|
(17,198 |
) |
|
|
(334 |
) |
|
|
898 |
|
|
|
5,150 |
|
|
|
15,852 |
|
|
|
15,141 |
|
Minority interest
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,164 |
|
|
|
22,781 |
|
|
|
22,335 |
|
|
|
2,918 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
(19,987 |
) |
|
|
8,319 |
|
|
|
(24,322 |
) |
|
|
(635 |
) |
|
|
2,752 |
|
|
|
22,388 |
|
|
|
21,127 |
|
|
|
9,015 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(490 |
) |
|
|
(2,373 |
) |
|
|
(2,227 |
) |
|
|
(214 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
(19,987 |
) |
|
$ |
8,319 |
|
|
$ |
(24,322 |
) |
|
$ |
(635 |
) |
|
$ |
2,262 |
|
|
$ |
20,015 |
|
|
$ |
18,900 |
|
|
$ |
8,801 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
54
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Alpha Natural | |
|
|
|
|
ANR Fund IX Holdings, L.P. and Alpha NR Holding, | |
|
Resources, Inc. | |
|
|
Predecessor | |
|
Inc. and Subsidiaries | |
|
and Subsidiaries | |
|
|
| |
|
| |
|
| |
|
|
Years Ended | |
|
January 1, | |
|
December 14, | |
|
|
|
Nine Months | |
|
Nine Months | |
|
|
December 31, | |
|
2002 to | |
|
2002 to | |
|
Year Ended | |
|
Year Ended | |
|
Ended | |
|
Ended | |
|
|
| |
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
December 31, | |
|
September 30, | |
|
September 30, | |
|
|
2000 | |
|
2001 | |
|
2002 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except per share amounts) | |
Earnings per share data(1):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per share, as adjusted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.19 |
|
|
$ |
1.52 |
|
|
$ |
1.43 |
|
|
$ |
0.17 |
|
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.04 |
) |
|
|
(0.16 |
) |
|
|
(0.15 |
) |
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic and diluted share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.15 |
|
|
$ |
1.36 |
|
|
$ |
1.28 |
|
|
$ |
0.16 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.02 |
|
|
$ |
0.55 |
|
|
$ |
0.53 |
|
|
$ |
0.18 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.01 |
) |
|
|
(0.06 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per basic share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.01 |
|
|
$ |
0.49 |
|
|
$ |
0.47 |
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per diluted share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.02 |
|
|
$ |
0.54 |
|
|
$ |
0.52 |
|
|
$ |
0.18 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.01 |
) |
|
|
(0.07 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per basic share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.01 |
|
|
$ |
0.47 |
|
|
$ |
0.46 |
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance sheet data (at period end):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
185 |
|
|
$ |
175 |
|
|
$ |
88 |
|
|
$ |
8,444 |
|
|
$ |
11,246 |
|
|
$ |
7,391 |
|
|
|
|
|
|
$ |
111 |
|
Operating and working capital
|
|
|
(26,634 |
) |
|
|
(22,958 |
) |
|
|
(4,268 |
) |
|
|
(12,223 |
) |
|
|
32,714 |
|
|
|
56,257 |
|
|
|
|
|
|
|
125,600 |
|
Total assets
|
|
|
130,608 |
|
|
|
139,467 |
|
|
|
156,328 |
|
|
|
108,442 |
|
|
|
379,336 |
|
|
|
477,121 |
|
|
|
|
|
|
|
622,098 |
|
Notes payable and long-term debt, including current portion
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
25,743 |
|
|
|
84,964 |
|
|
|
201,705 |
|
|
|
|
|
|
|
261,024 |
|
Stockholders equity and partners capital (deficit)
|
|
|
(142,067 |
) |
|
|
(136,593 |
) |
|
|
(132,997 |
) |
|
|
23,384 |
|
|
|
86,367 |
|
|
|
45,933 |
|
|
|
|
|
|
|
134,473 |
|
Statement of cash flows data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating activities
|
|
$ |
20,659 |
|
|
$ |
10,655 |
|
|
$ |
(13,816 |
) |
|
$ |
(295 |
) |
|
$ |
54,104 |
|
|
$ |
106,776 |
|
|
$ |
99,247 |
|
|
$ |
21,624 |
|
|
Investing activities
|
|
|
(8,564 |
) |
|
|
(9,203 |
) |
|
|
(22,054 |
) |
|
|
(38,893 |
) |
|
|
(100,072 |
) |
|
|
(86,202 |
) |
|
|
(67,235 |
) |
|
|
(93,390 |
) |
|
Financing activities
|
|
|
(12,106 |
) |
|
|
(1,462 |
) |
|
|
35,783 |
|
|
|
47,632 |
|
|
|
48,770 |
|
|
|
(24,429 |
) |
|
|
(27,447 |
) |
|
|
64,486 |
|
Capital expenditures
|
|
|
9,127 |
|
|
|
10,218 |
|
|
|
21,866 |
|
|
|
960 |
|
|
|
27,719 |
|
|
|
72,046 |
|
|
|
52,984 |
|
|
|
95,919 |
|
|
|
(1) |
Basic earnings per share is computed by dividing net income or
loss by the weighted average number of shares of common stock
outstanding during the periods. Diluted earnings per share is
computed by dividing net income or loss by the weighted average
number of shares of common stock and dilutive common stock
equivalents outstanding during the periods. Common stock
equivalents include the number of shares issuable on exercise of
outstanding options less the number of shares that could have
been purchased with the proceeds from the exercise of the
options based on the average price of common stock during the
period. |
|
|
|
We have disclosed for informational purposes two sets of
earnings per share data: |
|
|
Net Income (Loss) Per Share, as Adjusted |
|
|
The first set of earnings per share data is labeled net
income (loss) per share, as adjusted. The numerator for
purposes of computing basic and diluted net income (loss) per
share, as adjusted, includes the reported net income (loss) and
a pro forma adjustment for income taxes to reflect the pro forma
income taxes for ANR Fund IX Holdings, L.P.s portion
of reported pre-tax income (loss), which would have been
recorded if the issuance of the shares of common stock received
by the First Reserve Stockholders in exchange for their
ownership in ANR Holdings in connection with the Internal
Restructuring had occurred as of January 1, 2003. For
purposes of the computation of basic and diluted net income
(loss) per share, as adjusted, the pro forma adjustment for
income taxes only applies to the percentage interest owned by
ANR Fund IX Holding, L.P., the non-taxable First Reserve
Stockholder. No pro forma adjustment for income taxes is
required for the percentage interest owned by Alpha NR Holding,
Inc., the taxable First Reserve Stockholder, because income
taxes have already been recorded in the historical results of
operations. Furthermore, no pro forma adjustment to reported net
income (loss) is necessary subsequent to February 11, 2005
because Alpha Natural Resources, Inc. is subject to income taxes. |
|
|
The denominator for purposes of computing basic net income
(loss) per share, as adjusted, reflects the retroactive impact
of the common shares received by the First Reserve Stockholders
in exchange for their ownership in ANR Holdings in connection
with the Internal Restructuring on a weighted-average
outstanding share basis as being outstanding as of
January 1, 2003. The common shares issued to the minority
interest owners of ANR Holdings in connection with the Internal
Restructuring, including the immediately vested shares granted
to management, have been reflected as being outstanding as of
February 11, 2005 for purposes of computing the basic net
income (loss) per share, as adjusted. The unvested shares
granted to management on February 11, 2005 that vest
monthly over the two-year period from January 1, 2005 to
December 31, 2006 are included in the |
55
|
|
|
basic net income (loss) per share, as adjusted, computation as
they vest on a weighted-average outstanding share basis starting
on February 11, 2005. The 33,925,000 new shares issued in
connection with the IPO have been reflected as being outstanding
since February 14, 2005, the date of the IPO, for purposes
of computing the basic net income (loss) per share, as adjusted. |
|
|
The unvested shares issued to management are considered options
for purposes of computing diluted net income (loss) per share,
as adjusted. Therefore, for diluted purposes, all remaining
unvested shares granted to management are added to the
denominator subsequent to February 11, 2005 using the
treasury stock method, if the effect is dilutive. In addition,
the treasury stock method is used for outstanding stock options,
if dilutive, beginning with the November 10, 2004 grant of
options to management to purchase units in Alpha Coal Management
that were automatically converted into options to purchase up to
596,985 shares of our common stock at an exercise price of
$12.73 per share. |
|
|
The computations of basic and diluted net income (loss) per
share, as adjusted, are set forth below: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
Years Ended December 31, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share and per share data) | |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported income from continuing operations
|
|
$ |
2,752 |
|
|
$ |
22,388 |
|
|
$ |
21,127 |
|
|
$ |
9,015 |
|
|
Deduct: Income tax effect of ANR Fund IX Holdings, L.P.
income from continuing operations prior to Internal Restructuring
|
|
|
(138 |
) |
|
|
(1,149 |
) |
|
|
(1,124 |
) |
|
|
(91 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
|
2,614 |
|
|
|
21,239 |
|
|
|
20,003 |
|
|
|
8,924 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported loss from discontinued operations
|
|
$ |
(490 |
) |
|
$ |
(2,373 |
) |
|
$ |
(2,227 |
) |
|
$ |
(214 |
) |
|
Add: Income tax effect of ANR Fund IX Holdings, L.P. income
from discontinued operations prior to Internal Restructuring
|
|
|
27 |
|
|
|
149 |
|
|
|
139 |
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations, as adjusted
|
|
|
(463 |
) |
|
|
(2,224 |
) |
|
|
(2,088 |
) |
|
|
(212 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income, as adjusted
|
|
$ |
2,151 |
|
|
$ |
19,015 |
|
|
$ |
17,915 |
|
|
$ |
8,712 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares basic
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
53,184,066 |
|
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
382,403 |
|
|
|
|
Weighted average shares diluted
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
13,998,911 |
|
|
|
53,566,469 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.19 |
|
|
$ |
1.52 |
|
|
$ |
1.43 |
|
|
$ |
0.17 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.04 |
) |
|
|
(0.16 |
) |
|
|
(0.15 |
) |
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.15 |
|
|
$ |
1.36 |
|
|
$ |
1.28 |
|
|
$ |
0.16 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per diluted share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.19 |
|
|
$ |
1.52 |
|
|
$ |
1.43 |
|
|
$ |
0.17 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.04 |
) |
|
|
(0.16 |
) |
|
|
(0.15 |
) |
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.15 |
|
|
$ |
1.36 |
|
|
$ |
1.28 |
|
|
$ |
0.16 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro Forma Net Income (Loss) Per Share |
|
|
The second set of earnings per share data is labeled pro
forma net income (loss) per share. The numerator for
purposes of computing basic and diluted pro forma net income
(loss) per share is based on net income, as adjusted
(as calculated above) and pro forma adjustments to reflect the
impact of: |
|
|
|
|
(i) |
the add back of minority interest for each period presented,
because the ownership held by the minority interest owners of
ANR Holdings were exchanged for shares of our common stock as
part of the Internal Restructuring; |
|
|
(ii) |
the additional income taxes that would have been incurred by us
on the minority interest added back; and |
|
|
(iii) |
the issuance of $175,000 principal amount of 10% senior
notes due 2012 by our subsidiaries Alpha Natural Resources, LLC
and Alpha Natural Resources Capital Corp. and the entry by Alpha
Natural Resources, LLC into a $175,000 credit facility in May
2004, in connection with the 2004 Financings, as if these
transactions had occurred on January 1, 2003. |
|
|
|
No pro forma adjustment to reported net income (loss) is
necessary subsequent to February 11, 2005. |
56
|
|
|
The denominator for purposes of computing basic pro forma net
income (loss) per share reflects: |
|
|
|
|
(i) |
the retroactive impact of the common shares received by the
First Reserve Stockholders in exchange for their ownership in
ANR Holdings in connection with the Internal Restructuring on a
weighted-average outstanding share basis as being outstanding as
of January 1, 2003; |
|
|
(ii) |
the retroactive impact of the common shares issued to the
minority interest owners of ANR Holdings in connection with the
Internal Restructuring, including the immediately vested shares
granted to management, on a weighted-average outstanding share
basis as being outstanding as of January 1, 2003; |
|
|
(iii) |
the unvested shares granted to management that vest over the
two-year period from January 1, 2005 to December 31,
2006, which have been included in the basic computation on a
weighted-average outstanding share basis based on the monthly
vesting beginning as of January 1, 2005; and |
|
|
(iv) |
the retroactive impact of the 33,925,000 new shares issued in
connection with the IPO on a weighted-average outstanding share
basis as being outstanding as of January 1, 2003 since 100%
of the net proceeds from the IPO was distributed to the previous
owners of ANR Holdings. |
|
|
|
The unvested shares issued to management are considered options
for purposes of computing diluted pro forma net income (loss)
per share. Therefore, for diluted purposes, all remaining
unvested shares granted to management would be added to the
denominator as of January 1, 2003 using the treasury stock
method, if the effect is dilutive. In addition, the treasury
stock method would be used for outstanding stock options, if
dilutive, beginning with the November 10, 2004 grant of
options to management to purchase units in Alpha Coal Management
that were automatically converted into options to purchase up to
596,985 shares of our common stock at an exercise price of
$12.73 per share. |
|
|
The computations of basic and diluted pro forma net income
(loss) per share, are set forth below: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
Years Ended December 31, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2003 | |
|
2004 | |
|
2004 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share and per share data) | |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
$ |
2,614 |
|
|
$ |
21,239 |
|
|
$ |
20,003 |
|
|
$ |
8,924 |
|
|
Add: Minority interest in income from continuing operations, net
of income tax effect
|
|
|
2,822 |
|
|
|
14,124 |
|
|
|
13,848 |
|
|
|
2,231 |
|
|
Add: Pro forma effects related to the 2003 Acquisitions, net of
income taxes(1)
|
|
|
3,507 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deduct: Pro forma effects of the 2004 Financings, net of income
taxes
|
|
|
(7,728 |
) |
|
|
(1,672 |
) |
|
|
(1,614 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
|
1,215 |
|
|
|
33,691 |
|
|
|
32,237 |
|
|
|
11,155 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations, as adjusted
|
|
$ |
(463 |
) |
|
$ |
(2,224 |
) |
|
$ |
(2,088 |
) |
|
$ |
(212 |
) |
|
Add: Minority interest in income (loss) from discontinued
operations, net of income tax effect
|
|
|
(216 |
) |
|
|
(1,830 |
) |
|
|
(1,719 |
) |
|
|
(55 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma loss from discontinued operations
|
|
|
(679 |
) |
|
|
(4,054 |
) |
|
|
(3,807 |
) |
|
|
(267 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
$ |
536 |
|
|
$ |
29,637 |
|
|
$ |
28,430 |
|
|
$ |
10,888 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares basic
|
|
|
60,867,650 |
|
|
|
60,867,650 |
|
|
|
60,867,650 |
|
|
|
61,092,832 |
|
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
1,541,936 |
|
|
|
1,541,936 |
|
|
|
379,183 |
|
|
|
584,389 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares diluted
|
|
|
62,409,586 |
|
|
|
62,409,586 |
|
|
|
61,246,833 |
|
|
|
61,677,221 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per basic share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.02 |
|
|
$ |
0.55 |
|
|
$ |
0.53 |
|
|
$ |
0.18 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.01 |
) |
|
|
(0.06 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.01 |
|
|
$ |
0.49 |
|
|
$ |
0.47 |
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per diluted share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.02 |
|
|
$ |
0.54 |
|
|
$ |
0.52 |
|
|
$ |
0.18 |
|
|
|
|
Income (loss) from discontinued operations
|
|
|
(0.01 |
) |
|
|
(0.07 |
) |
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
0.01 |
|
|
$ |
0.47 |
|
|
$ |
0.46 |
|
|
$ |
0.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
See Managements Discussion and Analysis of Financial
Condition and Results of Operations
Overview Predecessor and 2003 Acquisitions for
a definition and explanation of the 2003
Acquisitions. |
57
MANAGEMENTS DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
You should read the following discussion and analysis in
conjunction with our financial statements and related notes, our
Unaudited Pro Forma Financial Information, and our
Selected Historical Financial Data included
elsewhere in this prospectus. The historical financial
information discussed below for periods prior to the completion
of our Internal Restructuring on February 11, 2005, is for
ANR Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
subsidiaries, which prior to the completion of our Internal
Restructuring were the owners of a majority of the membership
interests of ANR Holdings, our top-tier holding company, and for
Alpha NR Holding, Inc. and subsidiaries for periods from and
after the completion of our Internal Restructuring.
Overview
We produce, process and sell steam and metallurgical coal from
seven regional business units, which, as of November 1,
2005, are supported by 44 active underground mines, 25 active
surface mines and 11 preparation plants located throughout
Virginia, West Virginia, Kentucky, and Pennsylvania. We also
sell coal produced by others, the majority of which we process
and/or blend with coal produced from our mines prior to resale,
providing us with a higher overall margin for the blended
product than if we had sold the coals separately. For the first
nine months of 2005 and in 2004, sales of steam coal accounted
for approximately 62% and 63%, respectively, of our coal sales
volume during such periods. Sales of metallurgical coal, which
generally sells at a premium over steam coal, accounted for
approximately 38% and 37%, respectively, of our coal sales
volume during such periods. Our sales of steam coal during 2004
and the first nine months of 2005 were made primarily to large
utilities and industrial customers in the Eastern region of the
United States, and our sales of metallurgical coal were made
primarily to steel companies in the Northeastern and Midwestern
regions of the United States and in several countries in Europe,
Asia and South America. Approximately 44% of our sales revenue
in the first nine months of 2005 and 47% of our sales revenue in
2004 was derived from sales made outside the United States,
primarily in Japan, Canada, Brazil, Korea and several countries
in Europe.
In addition, we generate other revenues from equipment and parts
sales, equipment repair income, rentals, royalties, commissions,
coal handling, terminal and processing fees, and coal and
environmental analysis fees. We also record revenue for freight
and handling charges incurred in delivering coal to our
customers, which we treat as being reimbursed by our customers.
However, these freight and handling revenues are offset by
equivalent freight and handling costs and do not contribute to
our profitability.
Our business is seasonal, with operating results varying from
quarter to quarter. We generally experience lower sales and
hence build coal inventory during the winter months primarily
due to the freezing of lakes that we use to transport coal to
some of our customers.
Our primary expenses are for wages and benefits, supply costs,
repair and maintenance expenditures, cost of purchased coal,
royalties, freight and handling costs, and taxes incurred in
selling our coal. Historically, our cost of coal sales per ton
is lower for sales of our produced and processed coal than for
sales of purchased coal that we do not process prior to resale.
We have one reportable segment, Coal Operations, which includes
all of our revenues and costs from coal production and sales,
freight and handling, rentals, commissions and coal handling and
processing operations. We report the revenues and costs from
rentals, commissions and coal handling and processing operations
in our other revenues and cost of other revenues, respectively.
Predecessor and 2003 Acquisitions. On December 13,
2002, we acquired our Predecessor, the majority of the Virginia
coal operations of Pittston Coal Company, from The Brinks
Company (formerly known as The Pittston Company), for
$62.9 million. On January 31, 2003, we acquired
Coastal Coal Company for $67.8 million. In connection with
our acquisition of Coastal Coal Company, we acquired an
overriding royalty interest in certain properties located in
Virginia and West Virginia owned by El Paso CPG Company for
$11.0 million in cash. Effective February 1, 2003, we
sold the overriding royalty
58
interest to affiliates of Natural Resource Partners, L.P.
(NRP) for $11.8 million in cash. Effective
April 1, 2003, we also sold substantially all of our
fee-owned Virginia mineral properties to NRP for approximately
$53.6 million in cash in a sale/leaseback transaction. On
March 11, 2003, we acquired AMCI for $121.3 million
and on November 17, 2003, we acquired the assets of Mears
for $38.0 million in cash. We refer to the acquisitions of
Coastal Coal Company, AMCI and Mears, collectively, as the
2003 Acquisitions.
Internal Restructuring and Our Initial Public Offering.
On February 11, 2005, we completed a series of transactions
in connection with the Internal Restructuring for the purpose of
transitioning our top-tier holding company from a limited
liability company to a corporation, and on February 18,
2005, we completed the initial public offering of our common
stock. Further information regarding our Internal Restructuring
and our initial public offering can be found in note 1 to
our combined financial statements included in this prospectus.
As a result of our initial public offering and our Internal
Restructuring, we have incurred during the period after the
initial public offering and Internal Restructuring and will
continue to incur additional expenses that we have not incurred
in prior periods, including expenses associated with compliance
with corporate governance and periodic financial reporting
requirements for public companies. Moreover, all of our income
is now subject to income tax and therefore the effective tax
rates reflected in our financial statements for periods prior to
the Internal Restructuring are not indicative of our effective
tax rates after our Internal Restructuring.
As part of our Internal Restructuring, our executive officers
and certain other key employees exchanged their interests in ANR
Holdings for shares of our common stock and the right to
participate in a distribution of the proceeds we received from
the underwriters as a result of the underwriters exercise
of their over-allotment option in connection with the initial
public offering. As a result, we recorded stock-based
compensation expense equal to the fair value of the unrestricted
shares issued and distributions paid in the amount of
$42.6 million for the nine months ended September 30,
2005. In addition, as a result of the conversion of outstanding
options held by members of our management to purchase units of
Alpha Coal Management into the ACM Converted Options, we
recorded stock-based compensation of $0.6 million in the
first nine months of 2005. The aggregate amount of stock-based
compensation expense and stock-based compensation we recorded in
the first nine months of 2005 was $43.2 million, equal to
the $42.6 million of expense associated with distributions
paid and the vested portions of shares issued in the Internal
Restructuring and amortization expense from the unvested
portions of shares issued in the Internal Restructuring, and
$0.6 million of amortization expense from the ACM Converted
Options. In addition, we had deferred stock-based compensation
at September 30, 2005 of $18.6 million, including
$16.0 million and $2.6 million related to our Internal
Restructuring and the ACM Converted Options, respectively, that
we will record as non-cash stock-based compensation expense over
the remaining term of the applicable two-year and five-year
vesting periods, respectively, thereby reducing our earnings in
those periods.
In connection with our Internal Restructuring, we assumed the
obligation of ANR Holdings to make distributions to
(1) affiliates of AMCI in an aggregate amount of
$6.0 million, representing the approximate incremental tax
resulting from the recognition of additional tax liability
resulting from our Internal Restructuring, and (2) First
Reserve Fund IX, L.P. in an aggregate amount of
approximately $4.5 million, representing the approximate
value of tax attributes conveyed as a result of the Internal
Restructuring (collectively, the Tax Distributions).
The Tax Distributions to affiliates of AMCI are payable in five
equal installments on the dates for which estimated income tax
payments are due in each of April 2005, June 2005, September
2005, January 2006 and April 2006. The first three of these
payments were made on April 15, 2005, June 15, 2005,
and September 15, 2005, in the amount of $1.2 million
each in cash. The Tax Distributions to First Reserve
Fund IX, L.P. will be paid in three installments of
approximately $2.1 million, $2.1 million and
$0.3 million on December 15, 2007, 2008 and 2009,
respectively. We will pay the Tax Distributions in cash or, to
the extent our subsidiaries are not permitted by the terms of
our credit facility or the indenture governing our senior notes
to distribute cash to us to pay the Tax Distributions, in shares
of our common stock.
59
NKC Disposition. On April 14, 2005, we sold the
assets of NKC to an unrelated third party for cash in the amount
of $4.4 million, plus an amount in cash equal to the fair
market value of NKCs coal inventory, and the assumption by
the buyer of certain liabilities of NKC. For the six months
ended June 30, 2005, NKC contributed revenues of
$4.5 million, an after-tax and minority interest loss of
$0.2 million on 0.1 million tons of steam coal sold.
In connection with the closing of the transaction, National King
Coal, LLC was renamed NatCoal LLC, and Gallup Transportation and
Transloading Company, LLC was renamed GTTC LLC. Giving effect to
this disposition as if it had occurred on January 1, 2005,
our revenues would have been reduced by $4.5 million and
our net income would have increased by $0.2 million. We
recorded a gain on this sale of $0.7 million and are
reporting NKC as discontinued operations for all periods
presented herein. Our historical financial statements have been
restated to report the disposition of NKC as discontinued
operations and the components of the operating results included
in discontinued operations are shown in footnote 30 to our
consolidated financial statements and footnote 11 to our
condensed consolidated financial statements included elsewhere
in this prospectus.
Nicewonder Acquisition and 2005 Financing. On
October 26, 2005, we completed the acquisition of certain
privately held coal reserves and operations of the Nicewonder
Coal Group in southern West Virginia and southwestern Virginia
for an aggregate purchase price of $315.2 million,
consisting of cash at closing in the amount of
$35.2 million, a cash tax payment of $1.9 million to
be made to the sellers in April 2006, estimated transaction
costs of $3.9 million, $221.0 million principal amount
of promissory installment notes of one of our indirect, wholly
owned subsidiaries, of which $181.1 million was paid on November
2, 2005 and $39.9 million is due on January 15, 2006, and
2,180,233 shares of our common stock valued at approximately
$53.2 million for accounting purposes. For this purpose,
the value of the common stock issued was based on the average
closing prices of our common stock for the five trading days
surrounding October 20, 2005, the date the number of shares
to be issued under the terms of the acquisition agreement became
fixed without subsequent revision. In connection with the
Nicewonder Acquisition, we also agreed to make royalty payments
to the former owners of the acquired companies in the amount of
$0.10 per ton of coal mined and sold from White Flame
Energys surface mine no. 10. The final cash purchase
price is subject to certain working capital and other
adjustments. The Nicewonder Acquisition consisted of the
purchase of the outstanding capital stock of White Flame Energy,
Inc., Twin Star Mining, Inc. and Nicewonder Contracting, Inc.,
the equity interests of Powers Shop, LLC and Buchanan Energy,
LLC and substantially all of the assets of Mate Creek Energy of
W. Va., Inc. and Virginia Energy Company, and the business of
Premium Energy, Inc.
Also on October 26, 2005, in connection with our
acquisition of the Nicewonder Coal Group, we entered into a new
$525.0 million credit facility consisting of a $250.0 term
loan facility and a $275.0 revolving credit facility. We used
the net proceeds of the term loan facility and a portion of the
proceeds from drawings under the revolving credit facility to
finance the Nicewonder Acquisition and to refinance our
$175.0 million prior credit facility.
As a result of the Nicewonder Acquisition, based on our
preliminary estimates of the fair values and lives assigned to
the assets and liabilities acquired we expect to record
approximately $6.9 million of goodwill which will be
subject to annual impairment testing, and approximately
$306.2 million of property plant and equipment and
intangibles that will be depreciated over the useful life of the
assets, resulting in approximately $51.0 million of
additional depreciation, depletion and amortization expense per
year for the approximately five-year average useful life of the
property, plant and equipment and intangibles. We are in the
process of completing an evaluation of the fair values and the
lives of the assets. Fair value adjustments reflected in the pro
forma financial statements included in our Unaudited Pro
Forma Financial Information elsewhere in this prospectus
may be subject to material revisions and adjustments pending
finalization of the evaluation. We expect that our average cost
of coal sales per ton including the Nicewonder Coal Group
operations will be lower than it would be without the Nicewonder
Coal Group operations, because all of the Nicewonder Coal Group
mining operations are surface mines, which historically have a
lower cost of coal sales per ton than underground mining
operations. We also expect that our average coal sales
realization per ton including the Nicewonder Coal Group
operations will be
60
lower than it would be without the Nicewonder Coal Group
operations, because our existing operations market a higher
percentage of our produced tons as higher-priced metallurgical
coal than the Nicewonder Coal Group operations. As a result of
the Nicewonder Acquisition and the 2005 Financing, we have
incurred and expect to continue to incur additional debt and
increased interest expense. If the Nicewonder Acquisition and
2005 Financing had occurred on January 1, 2004, we would
have incurred additional interest expense of $15.2 million
and $11.5 million during the year ended December 31,
2004 and the nine months ended September, 2005, respectively.
On a pro forma basis as if the 2004 Financings, Internal
Restructuring, IPO and Nicewonder Acquisition and 2005 Financing
had each occurred on January 1, 2004, our revenues would
have been $1,397.3 million and $1,284.3 million and
our income from continuing operations would have been
$15.7 million and $12.5 million, respectively, for the
year ended December 31, 2004 and the nine months ended
September 30, 2005.
Coal Pricing Trends and Uncertainties. During 2004 and
the nine months ended September 30, 2005, prices for our
coal increased due to a combination of conditions in the United
States and internationally, including an improving
U.S. economy and robust economic growth in Asia, relatively
low customer stockpiles, limited availability of high-quality
coal from competing producers in Central Appalachia, capacity
constraints of U.S. nuclear-powered electricity generators,
high current and forward prices for natural gas and oil, and
increased international demand for U.S. coal. This strong
coal pricing environment has contributed to our growth in
revenues during 2004 and the nine months ended
September 30, 2005. While our outlook on coal pricing
remains positive, future coal prices are subject to factors
beyond our control and we cannot predict whether and for how
long this strong coal pricing environment will continue. As of
December 31, 2005, approximately 12%, 54% and 77%,
respectively, of our planned production for 2006, 2007 and 2008,
including production from the operations we acquired in the
Nicewonder Acquisition, was uncommitted and was not yet priced.
For the tons for which we have firm commitments in 2006, the
average price for steam coal is $46.79 per ton and the
average price for metallurgical coal is $73.91 per ton.
During 2004 and the first nine months of 2005, we experienced
increased costs for purchased coal which have risen with coal
prices generally, and increased operating costs for steel
manufactured equipment and supplies, employee wages and salaries
and contract mining and trucking. We anticipate that cost
pressures will persist in 2006, including higher costs for
purchased coal, contractor mining, trucking and general mining
supplies. Variable costs such as royalties and severance taxes
are also expected to rise in 2006 in parallel with rising sales
volumes. We also experienced disruptions in railroad service
beginning in the second half of 2004 and continuing through
2005, which caused delays in delivering products to customers
and increased our internal coal handling costs at our
operations. We expect disruptions in railroad service to
continue during 2006. Conditions affecting railroad service are
subject to factors beyond our control and we cannot predict
whether and for how long these railroad-related costs will
continue to increase in the future.
We experienced a tight market for supplies of mining and
processing equipment and parts during 2004 and the first nine
months of 2005, due to increased demand by coal producers
attempting to increase production in response to the strong
market demand for coal. Although we are attempting to obtain
adequate supplies of mining and processing equipment and parts
to meet our production forecasts, continued limited availability
of equipment and parts could prevent us from meeting those
forecasts. The supply of mining and processing equipment and
parts is subject to factors beyond our control and we cannot
predict whether and for how long this supply market will remain
limited.
We are also experiencing a tight market for skilled mining
employees and certified supervisors, due to increased demand by
coal producers attempting to increase production in response to
the strong market demand for coal, and demographic changes as
existing miners in Appalachia retire at a faster rate than new
miners are added to the Appalachian mining workforce. Although
we have initiated training programs to create new skilled miners
and raise the skill levels of existing miners, continued limited
availability of skilled miners could prevent us from being able
to meet our production and sales forecasts. The supply of
61
skilled mining employees is subject to factors beyond our
control and we cannot predict whether and for how long this
employee market will remain limited.
Due to Hurricane Katrina, we recorded a net pre-tax charge of
$0.7 million in the third quarter of 2005 for loss of
tonnage at a coal loading facility in New Orleans, representing
the estimated total loss less the portion of the loss expected
to be recovered through insurance claims. We expect to make a
final determination of the loss during the process of preparing
our financial statements for the fourth quarter of 2005.
For additional information regarding some of the risks and
uncertainties that affect our business, see Risks
Factors Risks Related to our Business.
Results of Operations
For purposes of the following discussion and analysis of our
operating results, the revenues and costs and expenses of ANR
Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
subsidiaries for the period from December 14, 2002 to
December 31, 2002 have been combined with the revenues and
costs and expenses of our Predecessor for the period from
January 1, 2002 to December 13, 2002, as reflected in
the table below. We believe this presentation facilitates the
ability of the reader to more meaningfully compare our revenues,
costs and expenses in 2002 with other periods. Our operating
results from and after December 14, 2002, including our
recorded depreciation, depletion and amortization expense, are
not comparable to the Predecessor Periods as a result of the
application of purchase accounting. The combining of the
Predecessor and successor accounting periods in the year ended
December 31, 2002 is not permitted by U.S. generally
accepted accounting principles.
62
Combined Statement of Operations Data
For the Year Ended December 31, 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ANR Fund IX | |
|
|
|
|
|
|
Holdings, L.P. and | |
|
|
|
|
|
|
Alpha NR | |
|
(Non- | |
|
|
|
|
Holding, Inc. and | |
|
GAAP) | |
|
|
Predecessor | |
|
Subsidiaries | |
|
Combined | |
|
|
| |
|
| |
|
| |
|
|
January 1, | |
|
December 14, | |
|
January 1, | |
|
|
2002 to | |
|
2002 to | |
|
2002 to | |
|
|
December 13, | |
|
December 31, | |
|
December 31, | |
|
|
2002 | |
|
2002 | |
|
2002 | |
|
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
154,715 |
|
|
$ |
6,260 |
|
|
$ |
160,975 |
|
|
Freight and handling revenues
|
|
|
17,001 |
|
|
|
1,009 |
|
|
|
18,010 |
|
|
Other revenues
|
|
|
6,031 |
|
|
|
101 |
|
|
|
6,132 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
177,747 |
|
|
|
7,370 |
|
|
|
185,117 |
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales (exclusive of items shown separately below)
|
|
|
158,924 |
|
|
|
6,268 |
|
|
|
165,192 |
|
|
Freight and handling costs
|
|
|
17,001 |
|
|
|
1,009 |
|
|
|
18,010 |
|
|
Cost of other revenues
|
|
|
7,973 |
|
|
|
120 |
|
|
|
8,093 |
|
|
Depreciation, depletion and amortization
|
|
|
6,814 |
|
|
|
274 |
|
|
|
7,088 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
8,797 |
|
|
|
471 |
|
|
|
9,268 |
|
|
Costs to exit business
|
|
|
25,274 |
|
|
|
|
|
|
|
25,274 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
224,783 |
|
|
|
8,142 |
|
|
|
232,925 |
|
|
|
|
|
|
|
|
|
|
|
Refund of federal black lung excise tax
|
|
|
2,049 |
|
|
|
|
|
|
|
2,049 |
|
Other operating income, net
|
|
|
1,430 |
|
|
|
|
|
|
|
1,430 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
$ |
(43,557 |
) |
|
$ |
(772 |
) |
|
$ |
(44,329 |
) |
|
|
|
|
|
|
|
|
|
|
Other Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
Tons sold
|
|
|
4,283 |
|
|
|
186 |
|
|
|
4,469 |
|
Coal sales realization per ton sold
|
|
$ |
36.12 |
|
|
$ |
33.66 |
|
|
$ |
36.02 |
|
Cost of coal sales per ton sold
|
|
$ |
37.11 |
|
|
$ |
33.70 |
|
|
$ |
36.96 |
|
The 2003 Acquisitions also affect comparability with the
Predecessor Periods and, therefore, the results of operations
for the Predecessor Periods are not comparable to the results of
operations for the periods from and after December 14,
2002. In addition, the results of operations for the year ended
December 31, 2004 are not directly comparable to the same
period in 2003 due to the 2003 Acquisitions.
|
|
|
Nine months Ended September 30, 2005 Compared to the
Nine months Ended September 30, 2004 |
For the nine months ended September 30, 2005, our total
revenues were $1.127 billion compared to
$924.3 million for the nine months ended September 30,
2004, an increase of $203.2 million. Net income decreased
from $18.9 million in the 2004 period to $8.8 million
for the 2005 period. Included in net income for the nine months
ended September 30, 2005, was a stock-based compensation
charge in the amount of $43.2 million ($40.5 million
after-tax) and gains associated with the settlement of a funded
reclamation settlement and the sale of NKC totaling
$2.5 million ($1.8 million after-tax). EBITDA, as adjusted
and as reconciled to our net income or loss in the table above,
was $91.2 million in the first nine
63
months of 2005, including the non-cash portion of the
stock-based compensation charge in the amount of
$35.7 million and was $5.5 million less than the same
period in 2004. Our pro forma earnings per diluted share were
$0.18 for the first nine months 2005, a $0.28 per share decrease
over pro forma earnings per share for the 2004 period (see
footnote 2 in our financial statements included herein). The
combination of the stock-based compensation charge and the gains
discussed above had a negative $0.63 effect on our pro forma
earnings per share for the first nine months of 2005.
We sold 18.9 million tons of coal during the first nine
months of 2005, 0.1 million less than the comparable period
in 2004. Coal margin increased from 16.5% in 2004 to 16.7% in
2005. Coal margin per ton was $8.67 in the nine months ended
September 30, 2005, an increase of 25% over the nine months
ended September 30, 2004 as increases in realization per
ton outpaced increases in cost of coal sales per ton.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
Increase | |
|
|
September 30, | |
|
(Decrease) | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
$ or Tons | |
|
% | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Coal revenues
|
|
$ |
982,383 |
|
|
$ |
801,021 |
|
|
$ |
181,362 |
|
|
|
23 |
% |
Freight and handling revenues
|
|
|
126,650 |
|
|
|
102,846 |
|
|
|
23,804 |
|
|
|
23 |
% |
Other revenues
|
|
|
18,447 |
|
|
|
20,440 |
|
|
|
(1,993 |
) |
|
|
(10 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$ |
1,127,480 |
|
|
$ |
924,307 |
|
|
$ |
203,173 |
|
|
|
22 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Tons Sold:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Steam
|
|
|
11,700 |
|
|
|
11,801 |
|
|
|
(101 |
) |
|
|
(1 |
)% |
Metallurgical
|
|
|
7,237 |
|
|
|
7,261 |
|
|
|
(24 |
) |
|
|
0 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
18,937 |
|
|
|
19,062 |
|
|
|
(125 |
) |
|
|
(1 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal sales realization per ton:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Steam
|
|
$ |
40.05 |
|
|
$ |
31.93 |
|
|
$ |
8.12 |
|
|
|
25 |
% |
Metallurgical
|
|
|
70.99 |
|
|
|
58.43 |
|
|
|
12.56 |
|
|
|
21 |
% |
Total
|
|
|
51.88 |
|
|
|
42.02 |
|
|
|
9.86 |
|
|
|
23 |
% |
Coal Revenues. Coal revenues increased by
$181.4 million during the nine months ended
September 30, 2005 over the comparable period of 2004, or
23% mainly driven by a 23% increase in coal sales realization
per ton from $42.02 per ton in the first nine months of
2004 to $51.88 per ton in the comparable 2005 period. Our met
coal realization per ton increased from $58.43 per ton in the
nine months ended September 30, 2004, to $70.99 per ton in
the 2005 nine month period, or 21%, and steam coal realization
per ton increased from $31.93 to $40.05 or 25%. Met coal sales
accounted for 38% of our coal sales volume in the nine months
ended September 30, 2005 and September 30, 2004. Total
tons sold during the first nine months of 2005 were
18.9 million, including 7.2 million tons of met coal
and 11.7 million of steam coal. Sales for the comparable
periods last year were 19.1 million tons of which
7.3 million tons were met coal and 11.8 million tons
were steam coal.
Freight and Handling Revenues. Freight and handling
revenues increased by $23.8 million during the nine months
ended September 30, 2005 over the year ago period mainly
due to higher freight rates partially offset by lower overseas
export volumes. However, these revenues are offset by equivalent
costs and do not contribute to our profitability.
Other Revenues. Other revenues decreased by
$2.0 million during the first nine months of this year from
the corresponding period last year mainly due to a
$2.4 million decrease in net sales commissions and lower
used equipment sales by Maxxim Rebuild in the approximate amount
of $1.2 million. Also, the nine months ended
September 30, 2004 included revenue from contract
reclamation in the amount of
64
$1.2 million and no income in the current period. These
decreases were partially offset by higher coal processing and
handling fees.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
Increase | |
|
|
September 30. | |
|
(Decrease) | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
$ | |
|
% | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Cost of coal sales (exclusive of items shown separately below)
|
|
$ |
818,299 |
|
|
$ |
668,887 |
|
|
$ |
149,412 |
|
|
|
22% |
|
Freight and handling costs
|
|
|
126,650 |
|
|
|
102,846 |
|
|
|
23,804 |
|
|
|
23% |
|
Cost of other revenues
|
|
|
16,327 |
|
|
|
14,942 |
|
|
|
1,385 |
|
|
|
9% |
|
Depreciation, depletion and amortization
|
|
|
45,521 |
|
|
|
38,883 |
|
|
|
6,638 |
|
|
|
17% |
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above and
including stock-based compensation expense in the amount of
$43,169 for the nine months ended September 30, 2005)
|
|
|
74,924 |
|
|
|
35,786 |
|
|
|
39,138 |
|
|
|
109% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
$ |
1,081,721 |
|
|
$ |
861,344 |
|
|
$ |
220,377 |
|
|
|
26% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales per ton:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Company mines
|
|
$ |
36.49 |
|
|
$ |
29.95 |
|
|
$ |
6.54 |
|
|
|
22% |
|
Contract mines (including purchased and processed)
|
|
|
50.54 |
|
|
|
39.97 |
|
|
|
10.57 |
|
|
|
26% |
|
|
Total produced and processed
|
|
|
39.46 |
|
|
|
32.22 |
|
|
|
7.24 |
|
|
|
22% |
|
Purchased and sold without processing
|
|
|
57.30 |
|
|
|
43.71 |
|
|
|
13.59 |
|
|
|
31% |
|
|
Cost of coal sales per ton
|
|
|
43.21 |
|
|
|
35.09 |
|
|
|
8.12 |
|
|
|
23% |
|
Cost of Coal Sales: Our cost of coal sales increased by
$149.4 million, or $8.12 per ton, from $668.9 million,
or $35.09 per ton, in the nine months ended September 30,
2004 to $818.3 million, or $43.21 per ton, in the 2005
comparable period. Our cost of sales per ton of our produced and
processed coal was $39.46 per ton in the nine months ended
September 30, 2005 as compared to $32.22 per ton in the
comparable period in 2004. This increase is attributable to
increased costs for steel-related mine supplies, higher trucking
costs, and increased variable sales-related costs, such as
royalties and severance taxes. Also, our cost for contract miner
services and coal purchased and processed at our facilities
increased 26% in the current period as compared to the prior
year period. In 2005, we have elected to take over production
for three of these under-performing contract mines and we have
incurred extra costs improve their operational and safety
standards. The cost of sales per ton of our purchased coal was
$57.30 per ton in the first nine months of 2005, and
$43.71 per ton for the corresponding period of 2004.
This $13.59 per ton increase in costs is due to the general
increase in coal prices since last year and the change in the
mix of coal qualities purchased. Of these purchased tons
approximately 62% was blended with our produced and processed
tons prior to resale.
Freight and Handling Costs. Freight and handling costs
increased by $23.8 million during the nine months ended
September 30, 2005 over the year ago period due higher
freight rates. We paid these freight and handling costs which we
treat as being reimbursed by our customers.
Cost of Other Revenues. Our cost of other revenues
increased by 9% or $1.4 million in the first nine months of
2005 when compared to the similar period in 2004 due to higher
coal processing and handling costs ($2.8 million) from
increased volumes partially offset by lower expenses at Maxxim
Rebuild related to lower sales levels ($1.4 million).
65
Depreciation, Depletion and Amortization. DD&A
increased $6.6 million or 17%, to $45.5 million for
the nine months ended September 30, 2005 as compared to the
same period in 2004 due mainly to capital additions. DD&A
per ton of produced and processed coal sold increased from $2.72
per ton for the nine months ended September 30, 2004 to
$3.05 per ton in the same period of 2005.
Selling, General and Administrative Expenses. Our
SG&A expenses increased by $39.1 million during the
first nine months of 2005 over the corresponding period last
year. Excluding our stock-based compensation charge of
$43.2 million incurred in the first nine months of 2005,
our SG&A expenses decreased in the nine months ended
September 30, 2005 by $4.0 million from the comparable
period last year. Included in the first nine months of 2004
expenses were incentive bonuses in the total amount of
$4.4 million and a $3.1 million payment related to
partial termination of a coal supply agreement. Included in this
years first nine months are higher professional fees
related to a strategic sourcing initiative, our Sarbanes-Oxley
compliance project and other expenses related to being a public
company. Excluding our stock-based compensation charge, our
SG&A was $1.68 and $1.88 per ton sold in 2005 and 2004,
respectively.
Interest Expense. Interest expense increased from
$14.5 million to $19.4 million during the nine months
ended September 30, 2005 compared to the same period in
2004. This increase is mainly attributable to our 10% senior
notes issued in May 2004.
Interest Income. Interest income increased by
$0.3 million in the nine months ended September 30,
2005 over the nine months ended September 30, 2004. This
increase was attributable to our $10.0 million loan to a
coal supplier which we made in June 2004.
Income Tax Expense: Our provision for income taxes
related to continuing operations increased by $9.3 million
from $5.9 million in the prior years first nine
months to $15.1 million in this years first nine
months. Since the condensed consolidated statements of
operations for the nine months ended September 30, 2005
include activity both prior to and after the Internal
Restructuring and IPO, the total income tax provision is the sum
of the provisions for the pre- and post-restructuring periods.
Prior to February 12, 2005, the minority interest owners
and ANR Fund IX Holdings, L.P. owned interests in
ANR Holdings, a limited liability company and pass-through
entity for income tax purposes. As a pass-through entity, ANR
Holdings provides information returns reflecting the allocated
income (loss) to the minority interest owners and ANR
Fund IX Holdings, L.P based upon their respective ownership
percentage and certain special allocations as provided by the
limited liability company agreement and the Internal Revenue
Code. The income tax consequences of the income
(loss) allocated to these owners for the period from
January 1, 2005 to February 11, 2005 and from
January 1, 2004 to September 30, 2004 is not reflected
in the financial statements. For these periods, only the income
tax expense associated with Alpha NR Holding, Inc., a taxable
entity, is included. The primary source of the income tax impact
is derived from the allocated income (loss) from ANR
Holdings, Alpha Natural Resources, LLC and its operating
subsidiaries, all of which are pass-through entities for tax
purposes. Subsequent to the Internal Restructuring and IPO, all
of the income of ANR Holdings is taxed to Alpha Natural
Resources, Inc.
The effective tax rate of 55.9% for the first nine months of
2005 is greater than the federal statutory rate of 35% due
primarily to the majority of the stock-based compensation charge
associated with the issuance of common stock to management in
connection with the Internal Restructuring and IPO not being
deductible for tax purposes. The increase in expected income tax
expense related to the stock-based compensation charge is offset
in part by the tax benefits associated with percentage
depletion, the extraterritorial income exclusion, and taxes not
being provided for on the minority interest and pass-through
entity owners respective share of income for the period
prior to the restructuring. As $33.0 million of the
stock-based compensation charge was identified as a significant
unusual item in the first quarter 2005, the tax effect of the
$33.0 million expense (no tax benefit) was accounted for in that
period and excluded from the estimated annual effective tax rate
of approximately 27%. The estimated effective tax rate for Alpha
Natural Resources, Inc. is applied to pre-tax income exclusive
of this significant unusual expense and infrequently occurring
item. Because the majority of the 2005 stock-based compensation
was
66
recorded in the first quarter, the first nine months of 2005
effective tax rate of 55.9%, including the negative impact of
the $33.0 million stock-based compensation charge, will not
be indicative of the effective tax rate for the remainder of
2005. We estimate that, exclusive of the stock-based
compensation charge (both the $33.0 million significant
unusual portion and the recurring portion for the full year of
2005), our 2005 effective tax rate would be approximately 23.5%,
which is lower than the federal statutory rate of 35% due to the
benefits of percentage depletion and a combination of the
Extraterritorial Income Exclusion and deduction for domestic
production activities enacted as part of the American Jobs
Creation Act of 2004, partially offset by state income taxes and
valuation allowances. Actual pre-tax income for the year and
continued quarterly review of valuation allowances could have an
impact on the fourth quarter and annual effective tax rate.
Our effective tax rate of 55.9% for the first nine months of
2005 is significantly higher than the rate of 11.9% in the first
nine months of 2004 primarily due to the significant stock-based
compensation charge for 2005 that did not exist in 2004. In
addition, the portion of pre-tax income related to the minority
interest and pass-through entity owners not tax affected is
greater in the first nine months of 2004, thereby reducing the
effective rate more in that period of 2004 compared to the same
period in 2005.
|
|
|
Year Ended December 31, 2004 Compared to Year Ended
December 31, 2003 |
For the year ended December 31, 2004, we recorded revenues
of $1,252.7 million compared to $781.8 million for the
year ended December 31, 2003, an increase of
$470.9 million over the previous year. Net income increased
from $2.3 million in 2003 to $20.0 million for 2004
and operating income increased $57.1 million to
$69.1 million. Tons sold increased from 21.6 million
tons in 2003 to 25.3 million tons in 2004 mainly due to the
impact of our 2003 Acquisitions. Coal margin, which we define as
coal revenues less cost of coal sales, divided by coal revenues,
increased from 9.8% in 2003 to 14.8% in 2004.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
Increase (Decrease) | |
|
|
| |
|
| |
|
|
2003 | |
|
2004 | |
|
$ or Tons | |
|
% | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Coal revenues
|
|
$ |
694,591 |
|
|
$ |
1,079,733 |
|
|
$ |
385,142 |
|
|
|
55% |
|
Freight and handling revenues
|
|
|
73,800 |
|
|
|
141,100 |
|
|
|
67,300 |
|
|
|
91% |
|
Other revenues
|
|
|
13,458 |
|
|
|
31,869 |
|
|
|
18,411 |
|
|
|
137% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$ |
781,849 |
|
|
$ |
1,252,702 |
|
|
$ |
470,853 |
|
|
|
60% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Tons sold
|
|
|
21,613 |
|
|
|
25,327 |
|
|
|
3,714 |
|
|
|
17% |
|
Coal sales realization per ton sold
|
|
$ |
32.14 |
|
|
$ |
42.63 |
|
|
$ |
10.49 |
|
|
|
33% |
|
Coal Revenues. Coal revenues increased for the year ended
December 31, 2004 by $385.1 million or 55%, to
$1,079.7 million, as compared to the year ended
December 31, 2003. This increase was due to a
$10.49 per ton increase in the average sales price of our
coal and the sale of 3.7 million additional tons over the
comparable period last year. The increase in the average sales
price of our coal was due to the general increase in coal prices
during the period and to our ability to take advantage of the
exceptionally high metallurgical coal sale prices by processing
and marketing as metallurgical coal some coal qualities that
would traditionally have been marketed as steam coal.
Approximately 63% and 37% of our tons sold during 2004 were
steam coal and metallurgical coal, respectively, as compared to
71% and 29% during the same period in 2003. Our tons sold in
2004 increased by 3.7 million, or 17%, to
25.3 million, primarily due to the effect of our 2003
Acquisitions, which provided approximately 3.4 million
additional tons.
Freight and Handling Revenues. Freight and handling
revenues increased to $141.1 million for the year ended
December 31, 2004, an increase of $67.3 million
compared to the year ended December 31,
67
2003 due to an increase of 3.4 million tons of export
shipments. However, these revenues are offset by equivalent
costs and do not contribute to our profitability.
Other Revenues. Other revenues increased for the year
ended December 31, 2004 by $18.4 million, or 137%, to
$31.9 million, as compared to the same period for 2003
primarily due to higher equipment and parts sales and equipment
repairs in the amount of $8.4 million, an increase in coal
handling and processing fees of $6.1 million, higher sales
commissions of $3.4 million, and trucking revenue of
$0.5 million. Other revenues for 2004 include a gain of
$1.5 million on the partial satisfaction of an obligation
to reclaim certain properties retained by the seller in the
Pittston acquisition. Other revenues attributable to our Coal
Operations segment were $13.8 million in 2004 and
$3.4 million in 2003.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
Increase (Decrease) | |
|
|
| |
|
| |
|
|
2003 | |
|
2004 | |
|
$ | |
|
% | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Cost of coal sales (exclusive of items shown separately below)
|
|
$ |
626,265 |
|
|
$ |
920,359 |
|
|
$ |
294,094 |
|
|
|
47% |
|
Freight and handling costs
|
|
|
73,800 |
|
|
|
141,100 |
|
|
|
67,300 |
|
|
|
91% |
|
Cost of other revenues
|
|
|
12,488 |
|
|
|
22,994 |
|
|
|
10,506 |
|
|
|
84% |
|
Depreciation, depletion and amortization
|
|
|
35,385 |
|
|
|
55,261 |
|
|
|
19,876 |
|
|
|
56% |
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
21,926 |
|
|
|
43,881 |
|
|
|
21,955 |
|
|
|
100% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
$ |
769,864 |
|
|
$ |
1,183,595 |
|
|
$ |
413,731 |
|
|
|
54% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales per ton sold
|
|
$ |
28.98 |
|
|
$ |
36.34 |
|
|
$ |
7.36 |
|
|
|
25% |
|
Cost of Coal Sales. For the year ended December 31,
2004, our cost of coal sales, which excludes charges for
depreciation, depletion and amortization and includes gain/loss
on sale of fixed assets, increased $294.1 million, or 47%,
to $920.4 million compared to the year ended
December 31, 2003. Our cost of coal sales increased as a
result of added costs involved in increasing the proportion of
our sales made to the metallurgical markets, such as higher
preparation and trucking costs, increased prices for
steel-related mine supplies, contract mining services, higher
prices for purchased coal, and increased variable sales-related
costs, such as royalties and severance taxes. Approximately
$80.0 million of the increase in the cost of coal sales was
due to the 2003 Acquisitions which provided approximately 87% of
our increase in tons sold. The average cost per ton sold
increased 25% from $28.98 per ton in 2003 to
$36.34 per ton in 2004. Our cost of coal sales as a
percentage of coal revenues decreased from 90% in 2003 to 85% in
2004. For the years ended December 31, 2004 and 2003 our
average cost per ton for our produced and processed coal sales
was $33.04 and $28.34, respectively, and our average cost per
ton for coal that we purchased from third parties and resold
without processing was $45.21 and $31.91, respectively. Cost of
coal sales in 2004 included $2.0 million of incentive bonus
payments and accruals.
Freight and Handling Costs. Freight and handling costs
increased $67.3 million to $141.1 million during 2004
as compared to 2003, mainly due to a 3.4 million ton
increase in export shipments where we paid the freight and
handling costs which we treated as being reimbursed by the
customer. These costs were offset by an equivalent amount of
freight and handling revenue.
Cost of Other Revenues. Cost of other revenues increased
$10.5 million, or 84%, to $23.0 million for the year
ended December 31, 2004 as compared to the prior year due
to higher volumes of equipment and part sales, equipment
repairs, and processing and handling fees. Cost of equipment
sales and repairs increased $7.3 million and processing and
handling costs increased $2.6 million for the year ended
December 31, 2004 as compared to the prior year. The cost
of trucking revenues increased by $0.5 million for 2004 as
compared to the prior year. Cost of other revenues attributable
to our Coal Operations segment were $7.4 million in 2004
and $2.3 million in 2003.
68
Depreciation, Depletion and Amortization. Depreciation,
depletion, and amortization increased $19.9 million, or
56%, to $55.3 million for the year ended December 31,
2004 as compared to the same period of 2003 due to capital
additions during 2004, resulting in additional depreciation of
approximately $9.1 million. The remaining increase is
attributable to the impact of the 2003 Acquisitions and 2003
capital additions of $27.7 million. Depreciation, depletion
and amortization attributable to our Coal Operations segment
were $51.7 million in 2004 and $32.5 million 2003.
Depreciation, depletion and amortization per ton increased from
$1.64 per ton for the year ended December 31, 2003 to
$2.18 per ton in the same period of 2004.
Selling, General and Administrative Expenses. Selling,
general and administrative expenses increased
$21.9 million, or 100%, to $43.9 million for the year
ended December 31, 2004 compared to the same period in
2003. The increase is attributed to higher staffing levels and
resulting salaries, wages and benefits of approximately
$4.7 million, increased incentive bonus payments and
accruals in the amount of $6.0 million, coal contract
buyouts of $3.3 million, increased professional fees of
approximately $3.2 million including $1.7 million
incurred in documenting, assessing, and improving our controls
and procedures due to the requirements of the Sarbanes-Oxley Act
of 2002, and a net increase in all other sales, general and
administrative expenses of approximately $4.7 million. Our
selling, general and administrative expenses as a percentage of
total revenues increased from 2.8% in 2003 to 3.5% in 2004.
Interest expense increased $12.2 million to
$20.0 million during 2004 compared to 2003. The increase
was mainly due to the additional interest expense of
$10.8 million related to our 10% senior notes issued
in May 2004 and the write-off of deferred financing costs of
$2.8 million related to our previous credit facility.
Interest income increased from $0.1 million to
$0.5 million as a result of interest received on notes
receivable issued in 2004.
Income tax expense increased $4.3 million to
$5.2 million for the year ended December 31, 2004 as
compared to the year ended December 31, 2003. Our effective
tax rates from continuing operations for the year ended
December 31, 2004 and 2003 were 10.2% and 18.7%,
respectively. The effective tax rates are lower than the
statutory tax rate since we are not subject to tax with respect
to the portion of our income before taxes which is attributable
to ANR Fund IX Holdings, L.P.s portion of our
earnings and the minority interests share in the earnings
of ANR Holdings. In addition, our taxable income is reduced by
percentage depletion allowances (computed as a percentage of
coal revenue, subject to certain income limitations) and the
extraterritorial income exclusion (ETI) deduction (computed
as a percentage of exported coal revenue, subject to certain
income limitations) which reduces our effective tax rates. These
reductions in our effective tax rates are offset by the effect
of increases in our valuation allowance for deferred tax assets
of $0.6 million and $0.8 million recorded in the year
ended December 31, 2004 and 2003, respectively. The
reduction in our effective tax rate in 2004 compared to 2003 is
due primarily to the ETI deduction in 2004 generated from
significant export coal revenue, a lower valuation allowance as
a percentage of pre-tax income in 2004, and a larger percentage
of minority interest in 2004 which has no income tax provision.
|
|
|
Year Ended December 31, 2003 Compared to Year Ended
December 31, 2002 |
For the year ended December 31, 2003, revenues increased
$596.7 million to $781.8 million over the combined
revenues for our Predecessor and successor accounting periods in
the year ended December 31, 2002. Net income and operating
income for the year ended December 31, 2003 were
$2.3 million and
69
$12.0 million, respectively. Net income and operating
income on a combined basis for 2002 are not comparable. Tons
sold increased from 4.5 million tons for the year ended
December 31, 2002 to 21.6 million tons in 2003 mainly
due to the impact of our 2003 Acquisitions. Coal margin
increased from (2.6)% in 2002 to 9.8% in 2003, mainly due to the
lower unit cost of coal sold provided by our 2003 Acquisitions.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
Increase (Decrease) | |
|
|
| |
|
| |
|
|
2002* | |
|
2003 | |
|
$ or Tons | |
|
% | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Coal revenues
|
|
$ |
160,975 |
|
|
$ |
694,591 |
|
|
$ |
533,616 |
|
|
|
331 |
% |
Freight and handling revenues
|
|
|
18,010 |
|
|
|
73,800 |
|
|
|
55,790 |
|
|
|
310 |
% |
Other revenues
|
|
|
6,132 |
|
|
|
13,458 |
|
|
|
7,326 |
|
|
|
119 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$ |
185,117 |
|
|
$ |
781,849 |
|
|
$ |
596,732 |
|
|
|
322 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Tons sold
|
|
|
4,469 |
|
|
|
21,613 |
|
|
|
17,144 |
|
|
|
384 |
% |
Coal sales realization per ton sold
|
|
$ |
36.02 |
|
|
$ |
32.14 |
|
|
$ |
(3.88 |
) |
|
|
(11 |
)% |
|
|
* |
Reflects the combination of the Predecessor and successor
accounting periods in the year ended December 31, 2002. |
Coal Revenues. Coal revenues increased
$533.6 million, or 331%, to $694.6 million for the
year ended December 31, 2003, from $161.0 million for
the year ended December 31, 2002. The increase was
primarily due to the 2003 Acquisitions, which contributed an
additional 15.7 million tons sold and approximately
$505.3 million in revenues, partially offset by a reduction
in the average sales price per ton of $3.88 or
$15.0 million in revenues. Tons sold increased from
4.5 million tons in 2002 to 21.6 million tons in 2003.
The 2003 Acquisitions accounted for 16.0 million of the
17.1 million ton increase in tons sold from 2002 to 2003.
Our average sales price per ton decreased 11% from
$36.02 per ton in 2002 to $32.14 per ton in 2003,
mainly due to our lower percentage of metallurgical coal sales
in 2003 as compared to sales of our Predecessor in 2002.
Approximately 71% and 29% of our tons sold in the 2003 were
steam coal and metallurgical coal, respectively, as compared to
45% and 55% during 2002.
Freight and Handling Revenues. Freight and handling
revenues increased $55.8 million from $18.0 million in
2002 due to increased volumes resulting from the 2003
Acquisitions, which contributed approximately $33.5 million
of the increase. An increase in overseas export tons of
approximately 1.1 million tons was responsible for most of
the remaining increase in freight and handling revenues. These
revenues were offset by equivalent costs and did not contribute
to our profitability.
Other Revenues. Other revenues, principally equipment
repair and sales, and coal handling, terminalling and processing
fees, rents and royalties increased $7.3 million to $13.5
for 2003, mainly due to the 2003 Acquisitions, coal handling,
terminalling and processing fees in the amount of
$2.8 million and royalty income of $1.3 million. Other
revenues for 2002 consisted of equipment repair and sales
income, which increased $1.7 million in 2003. Other
revenues attributable to our Coal Operations segment were
$3.4 million for the year ended December 31, 2003, and
we had no other revenues attributable to our Coal Operations
segment for the year ended December 31, 2002.
70
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
Increase (Decrease) | |
|
|
| |
|
| |
|
|
2002* | |
|
2003 | |
|
$ | |
|
% | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per ton data) | |
Cost of coal sales (exclusive of items shown separately below)
|
|
$ |
165,192 |
|
|
$ |
626,265 |
|
|
$ |
461,073 |
|
|
|
279 |
% |
Freight and handling costs
|
|
|
18,010 |
|
|
|
73,800 |
|
|
|
55,790 |
|
|
|
310 |
% |
Cost of other revenues
|
|
|
8,093 |
|
|
|
12,488 |
|
|
|
4,395 |
|
|
|
54 |
% |
Depreciation, depletion and amortization
|
|
|
7,088 |
|
|
|
35,385 |
|
|
|
28,297 |
|
|
|
399 |
% |
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
9,268 |
|
|
|
21,926 |
|
|
|
12,658 |
|
|
|
137 |
% |
Costs to exit business
|
|
|
25,274 |
|
|
|
|
|
|
|
(25,274 |
) |
|
|
(100 |
)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
$ |
232,925 |
|
|
$ |
769,864 |
|
|
$ |
536,939 |
|
|
|
231 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales per ton sold
|
|
$ |
36.96 |
|
|
$ |
28.98 |
|
|
$ |
(7.99 |
) |
|
|
(22 |
)% |
|
|
* |
Reflects the combination of the Predecessor and successor
accounting periods in the year ended December 31, 2002. |
Cost of Coal Sales. Our cost of coal sales increased
$461.1 million, or 279%, to $626.3 million for the
year ended December 31, 2003, from $165.2 million for
the year ended December 31, 2002. The 2003 Acquisitions
accounted for $454.7 million of the increase in our cost of
coal sales and for 93% of the 12.6 million ton increase in
our produced and processed coal sales for 2003. The average cost
per ton sold decreased 22% from $36.96 per ton in 2002 to
$28.98 per ton in 2003 as a result of increased production,
which reduced our fixed costs per ton, as well as lower costs of
coal produced from mines acquired in the 2003 Acquisitions. Our
cost of coal sales as a percentage of coal revenues decreased
from 103% in 2002 to 90% in 2003.
Freight and Handling Costs. Freight and handling costs
increased $55.8 million to $73.8 million for the year
ended December 31, 2003 as compared to the prior period,
primarily due to increased sales volumes resulting from the 2003
Acquisitions, which contributed approximately $33.5 million
of the increase. An increase in overseas export tons of
approximately 1.1 million tons was responsible for most of
the remaining increase in freight and handling costs. These
costs are offset by an equivalent amount of freight and handling
revenue.
Cost of Other Revenues. Cost of other revenues increased
$4.4 million, or 54%, to $12.5 million for 2003 as
compared to 2002 as a result of the 2003 Acquisitions, in which
we acquired coal processing operations, and their related costs
of $4.3 million, as the cost for 2002 includes only those
related to equipment repair and sales income, which remained
relatively unchanged. Cost of equipment repair and sales for
2002 included a litigation settlement, therefore cost for 2003
did not increase over 2002 with the increased sales volumes.
Cost of other revenues attributable to our Coal Operations
segment were $2.3 million for the year ended
December 31, 2003 and we had no cost of other revenues
attributable to our Coal Operations segment for the year ended
December 31, 2002.
Depreciation, Depletion and Amortization. Depreciation,
depletion and amortization expense for the year ended
December 31, 2003 was $35.4 million, an increase of
$28.3 million from the prior year. The increase in expense
is attributable to the 2003 Acquisitions, and the 2003 capital
additions of $27.7 million, as depreciation, depletion and
amortization expense per ton showed only a slight increase from
$1.59 per ton in 2002 to $1.64 per ton in 2003.
Depreciation, depletion and amortization attributable to our
Coal Operations segment were $32.5 million for the year
ended December 31, 2003 and $7.0 million for the year
ended December 31, 2002.
Selling, General and Administrative Expenses. Selling,
general and administrative expenses increased by
$12.7 million to $21.9 million, but decreased from
$2.07 per ton sold to $1.00 per ton sold from 2002 to
71
2003, primarily due to a significant increase in tons sold,
partially offset by additional expenses of $2.0 million
associated with transition services provided by the selling
companies. Our selling, general and administrative expenses as a
percentage of total revenues decreased from 5.0% in 2002 to 2.8%
in 2003.
Costs to Exit Business. For the year ended
December 31, 2002, our Predecessor recorded a charge of
$25.3 million for a pension plan early withdrawal penalty.
The early withdrawal penalty was incurred when our Predecessor
withdrew from a multi-employer pension plan when we purchased
their operations.
Interest expense increased to $7.8 million for the year
ended December 31, 2003 from $0.2 million for the
period from January 1, 2002 to December 13, 2002. The
increase is due to interest on loans to finance the 2003
Acquisitions.
Interest income decreased from $2.1 million for the period
from January 1 to December 13, 2002 to
$0.1 million in 2003. Interest income for the period from
January 1, 2002 to December 13, 2002 was attributable
to interest earned on Virginia tax credits and an employee
benefit trust. We did not acquire the assets of the employee
benefit trust or the receivable for the Virginia tax credits.
|
|
|
Income Tax Expense (Benefit) |
Income taxes from continuing operations increased
$18.1 million from a benefit of $17.2 million for the
period from January 1, 2002 to December 13, 2002 to an
expense of $0.9 million for the year ended
December 31, 2003. This increase in income taxes was
attributable primarily to the increase in pre-tax income. The
effective tax rate for the period from January 1, 2002 to
December 13, 2002 and for the year ended December 31,
2003 was 41.4% and 18.7%, respectively. In 2003, tax was not
provided on ANR Fund IX Holdings, L.P.s portion of
our earnings and the minority interest owners share in the
earnings of ANR Holdings. In addition, in periods when a pre-tax
loss is reported, percentage depletion increases the effective
tax rate (increases the tax benefit) whereas in periods when
pre-tax income is reported, percentage depletion decreases the
effective tax rate (decreases the tax expense).
Liquidity and Capital Resources
Our primary liquidity and capital resource requirements are to
finance the cost of our coal production and purchases, to make
capital expenditures, pay income taxes, and to service our debt
and reclamation obligations. Our primary sources of liquidity
are cash flow from sales of our produced and purchased coal,
other income and borrowings under our senior credit facility.
At September 30, 2005, our available liquidity was
$41.1 million, including cash of $0.1 million and
$41.0 million available under our then-existing credit
facility. Our total indebtedness was $261.0 million at
September 30, 2005, an increase of $59.3 million from
the year ended December 31, 2004. As previously discussed, on
October 26, 2005, we closed our 2005 Financing. Giving
effect to this new credit facility, the closing of the
Nicewonder Acquisition and the repayment of the first
installment of the promissory installment notes issued to the
sellers in connection with the Nicewonder Acquisition, in each
case as if these transactions had occurred on September 30,
2005, our estimated availability would have been approximately
$154.2 million and our total outstanding indebtedness would
have been approximately $525.2 million.
Our cash capital spending for the nine months ended
September 30, 2005 was $95.9 million, and we expect to
spend from $110.0 million to $120.0 million for the
full year and from $140.0 million to $150.0 million
for 2006. These expenditures have been and will be used to
develop new mines and replace or add equipment. Based on the
terms of our outstanding capital lease obligations and
indebtedness as of December 1, 2005, projected 2006
payments of principal on capital lease obligations and
indebtedness, including repayment of the final installment due
on the promissory notes issued to the sellers in connection
72
with the Nicewonder Acquisition, are $43.3 million in the
aggregate, of which $40.9 million is payable in the first
quarter of 2006, and $0.8 million is payable in each of the
three succeeding quarters. Based on our projection of cash to be
generated from operations in 2006 and projected availability
under our revolving line of credit, which we estimate to have
been $154.2 million as of September 30, 2005 (giving
effect to our new credit facility and the closing of the
Nicewonder Acquisition as if these transactions had occurred at
that date), we believe that cash from operations and available
borrowings will be sufficient to meet our working capital
requirements, anticipated capital expenditures and debt
repayment requirements during each quarter of 2006.
Net cash provided by operations in the first nine months of 2005
was $21.6 million, a decrease of $77.6 million from
the $99.2 million of net cash provided by operations during
the first nine months of 2004. A decrease in our net income and
an increase in our non-cash charges (mainly due to our
stock-based compensation) provided more cash in the nine months
ended September 30, 2005 than the comparable period in 2004
in the amount of $6.6 million. However, the
$6.6 million was more than offset by an increase in the
cash required to support our operating assets and liabilities in
the amount of $84.3 million. The additional cash required
for operating assets and liabilities in the first nine months of
2005 as compared to the first nine months of 2004 was
principally caused by the following three factors:
|
|
|
|
|
Our trade accounts receivable used $28.5 million more cash
in the first nine months of 2005 than in the comparable period
last year, due to the 22% increase in our total revenues in the
nine months ended September 30, 2005 compared to the prior
year period. Our days sales outstanding as of
September 30, 2005 were 34.8 days an increase of
1.9 days from June 30, 2005. This increase was due to
shipments to customers whose regular terms of sale require them
to pay us within 60 days. |
|
|
|
The cash required to carry inventories increased by
$28.5 million in the current nine month period over the
corresponding period last year mainly due to an increase in tons
in inventory and an increase in the associated cost per ton. |
|
|
|
Accounts payable and other current accrued liabilities provided
cash in the nine months ended September 30, 2005 in the
amount of $16.2 million while these liabilities provided
cash in the amount of $44.9 million in the year ago period,
an additional $28.7 million use of cash in the current
period. |
Net cash used in investing activities consumed
$26.2 million more cash in the first nine months of 2005
over the year ago period mainly due to increased capital
expenditures for new mines and equipment.
Net cash provided by financing activities increased by
$91.9 million to $64.5 million in the nine months
ended September 30, 2005 over the nine months ended
September 30, 2004. During the nine month period ending
September 30, 2004 we recapitalized our company by issuing
$175.0 million of 10% senior notes and entered into a new
credit facility. We used the proceeds to repay our then existing
credit facility and to pay distributions to the members of ANR
Holdings, LLC. Net cash used by financing activities was
$27.4 million during the year ago period. In the nine
months ended September 30, 2005, we completed our
previously discussed Internal Restructuring and IPO. The
proceeds from the IPO were used to repay shareholders
notes issued as part of the Internal Restructuring. Our
long-term debt increased
73
approximately $72.0 million during 2005 and has been used
to fund our cash needs for working capital and to purchase
capital equipment.
Cash provided by operating activities was $106.8 million
for the year ended December 31, 2004, an increase of
$52.7 million from the same period in 2003. Cash provided
by operations for 2004 benefited from the effects of our 2003
Acquisitions and the strength of the coal markets during the
period. This increase is attributable to an increase in net
income of $17.7 million for 2004 over 2003, an increase in
non-cash charges included in net income of $49.9 million
and partially offset by the effects of a $15.0 million
increase in net operating assets and liabilities.
Net cash used in investing activities was $86.2 million
during the year ended December 31, 2004, $13.9 million
less than the same period of 2003. Capital expenditures
increased $44.3 million, to $72.0 million during 2004.
The increase in capital expenditures was primarily due to the
replacement of equipment, new mine development and upgrades to a
preparation plant. In the second quarter of 2003, we sold our
interest in certain coal properties acquired in the purchase of
our Predecessor, and a royalty interest acquired in our Coastal
Coal Company acquisition for cash of $65.2 million. We also
paid $133.8 million for the Coastal Coal Company,
U.S. AMCI and Mears acquisitions in 2003. As part of a coal
supply agreement, we loaned an unrelated coal supplier
$10.0 million in June 2004 at a variable rate to be repaid
in installments over a two-year period beginning in August 2004.
The loan is secured by the assets of the debtor and personally
guaranteed by the debtors owner. The related coal supply
agreement with the debtor should provide us with approximately
40,000 tons of coal per month through March of 2006. In
September 2004, we also acquired an equity interest for a
subscription price of $6.5 million in a company which is
developing a mining property in Venezuela. Payments totaling
$4.5 million were made during the year ended
December 31, 2004.
Net cash used in financing activities during the year ended
December 31, 2004 was $24.4 million compared with net
cash provided by financing activities of $48.8 million in
the prior year. Net cash used by financing activities included
the net proceeds of $171.5 million received as a result of
the issuance of our $175 million 10% senior notes in
May 2004 offset by distributions made to our equity owners of
$115.6 million, the repayment of bank and other debt in the
amount of $75.8 million, $10.5 million paid for debt
issuance costs and $1.7 for deferred stock offering costs during
the year ended December 31, 2004. We received
$18.3 million in capital contributions and
$20.0 million in advances from affiliates during the year
ended December 31, 2003. In addition, we incurred bank and
other debt in the net amount of $12.9 million during the
year ended December 31, 2003.
Our operations provided us cash of $54.1 million for the
year ended December 31, 2003, while the operations of our
Predecessor used cash of $13.8 million for the period from
January 1, 2002 to December 13, 2002. Our net income
increased $26.6 million to $2.3 million when compared
to our Predecessors net loss of $24.3 million. Our
non-cash charges increased by $36.8 million in 2003 mainly
due to increased depreciation, depletion and amortization
charges associated with the 2003 Acquisitions. Net changes in
operating assets and liabilities increased our operating cash
flow by $15.1 million in 2003 while net changes in
operating assets and liabilities increased cash flow from
operations by $11.3 million for the period from
January 1, 2002 to December 13, 2002.
Net cash used in investing activities was $100.1 million
for the year ended December 31, 2003. Cash used in
investing activities includes $133.8 million for the
acquisitions of Coastal Coal Company, U.S. AMCI, and Mears
and capital expenditures of $27.7 million. The 2003 period
includes proceeds of $65.2 million received from the sales
of coal reserves and mineral interests acquired in the Pittston
Coal Company and Coastal Coal Company acquisitions. The
investing activities of our Predecessor in 2002 consisted
primarily of capital expenditures.
Net cash provided by financing activities was $48.8 million
and $35.8 million for the year ended December 31, 2003
and the period from January 1, 2002 to December 13,
2002, respectively. In 2003, we entered into a credit facility
which provided for a $45.0 million term loan and a
$75.0 million revolving credit line.
74
Proceeds from borrowings under this credit facility were
$58.5 million in 2003. Repayments of notes payable and
long-term debt totaled $45.7 million. We received
$15.2 million for common stock issued and we received
advances from affiliates of $20.0 million during the year
ended December 31, 2003. Cash provided by financing
activities of our Predecessor in the period from January 1,
2002 to December 13, 2002 consisted of advances from
affiliates.
|
|
|
Credit Facility and Long-term Debt |
As of September 30, 2005, our total long-term indebtedness,
including capital lease obligations, consisted of the following
(in thousands):
|
|
|
|
|
|
|
September 30, | |
|
|
2005 | |
|
|
| |
10% Senior notes due 2012
|
|
$ |
175,000 |
|
Revolving credit facility
|
|
|
81,000 |
|
Variable rate term notes
|
|
|
586 |
|
Capital lease obligation
|
|
|
1,623 |
|
|
|
|
|
Total long-term debt
|
|
|
258,209 |
|
Less current portion
|
|
|
(1,046 |
) |
|
|
|
|
Long-term debt, net of current portion
|
|
$ |
257,163 |
|
|
|
|
|
Our prior credit facility imposed, and our new credit facility
and the indenture governing the senior notes each impose,
certain restrictions on our subsidiaries, including restrictions
on our subsidiaries ability to: incur debt; grant liens;
enter into agreements with negative pledge clauses; provide
guarantees in respect of obligations of any other person; pay
dividends and make other distributions; make loans, investments,
advances and acquisitions; sell assets; make redemptions and
repurchases of capital stock; make capital expenditures; prepay,
redeem or repurchase debt; liquidate or dissolve; engage in
mergers or consolidations; engage in affiliate transactions;
change businesses; change our fiscal year; amend certain debt
and other material agreements; issue and sell capital stock of
subsidiaries; engage in sale and leaseback transactions; and
restrict distributions from subsidiaries. In addition, similar
to our prior credit facility, the new credit facility provides
that we must meet or exceed certain interest coverage ratios and
must not exceed certain leverage ratios.
Borrowings under our new credit facility will be subject to
mandatory prepayment (1) with 100% of the net cash proceeds
received from asset sales or other dispositions of property by
Alpha NR Holding, Inc. and its subsidiaries (including insurance
and other condemnation proceedings), subject to certain
exceptions and reinvestment provisions, and (2) with 100%
of the net cash proceeds received by Alpha NR Holding, Inc. and
its subsidiaries from the issuance of debt securities or other
incurrence of debt, excluding certain indebtedness.
As a regular part of our business, we review opportunities for,
and engage in discussions and negotiations concerning, the
acquisition of coal mining assets and interests in coal mining
companies, and acquisitions of, or combinations with, coal
mining companies. When we believe that these opportunities are
consistent with our growth plans and our acquisition criteria,
we will make bids or proposals and/or enter into letters of
intent and other similar agreements, which may be binding or
nonbinding, that are customarily subject to a variety of
conditions and usually permit us to terminate the discussions
and any related agreement if, among other things, we are not
satisfied with the results of our due diligence investigation.
Any acquisition opportunities we pursue could materially affect
our liquidity and capital resources and may require us to incur
indebtedness, seek equity capital or both. There can be no
assurance that additional financing will be available on terms
acceptable to us, or at all.
75
|
|
|
Analysis of Material Debt Covenants |
We were in compliance with all covenants under our prior credit
facility and the indenture governing our senior notes as of
September 30, 2005.
The financial covenants in our prior credit facility required,
among other things, that:
|
|
|
|
|
Alpha Natural Resources, LLC, our indirect wholly-owned
subsidiary, maintain a leverage ratio, defined as the ratio of
total debt to Adjusted EBITDA (as defined in the prior credit
agreement), of not more than 3.50 at September 30, 2005
with Adjusted EBITDA being computed using the most recent four
quarters; and |
|
|
|
Alpha Natural Resources, LLC maintain an interest coverage
ratio, defined as the ratio of Adjusted EBITDA (as defined in
the prior credit agreement), to cash interest expense (defined
as the sum of cash interest expense plus cash letter of credit
fees and commissions), of 2.50 or greater at September 30,
2005. |
Based upon Adjusted EBITDA (as defined in the prior credit
agreement), Alpha Natural Resources, LLCs leverage ratio
and interest coverage ratio for the twelve months ended
September 30, 2005 were 1.66 (maximum of 3.50) and 8.80
(minimum of 2.50), respectively. Alpha Natural Resources, LLC
maintained the leverage and interest coverage ratios specified
in, and were in compliance with, the prior credit facility as of
September 30, 2005.
Adjusted EBITDA, as defined in the prior credit agreement, was
used to determine compliance with many of the covenants under
the prior credit facility. The breach of covenants in the prior
credit facility that were tied to ratios based on Adjusted
EBITDA could have resulted in a default under the old credit
facility and the lenders could have elected to declare all
amounts borrowed due and payable.
The financial covenants in the new credit facility require,
among other things, that:
|
|
|
|
|
Alpha NR Holding Inc. must maintain a leverage ratio, defined as
the ratio of consolidated adjusted debt (consolidated debt less
unrestricted cash and cash equivalents) to Adjusted EBITDA (as
defined in the new credit agreement), of not more than 4.00 at
December 31, 2005, March 31, June 30, September
30 and December 31, 2006, 3.75 at March 31,
June 30, September 30 and December 31, 2007, and 3.50
at March 31, 2008 and each quarter end thereafter, with
Adjusted EBITDA being computed using the most recent four
quarters; and |
|
|
|
Alpha NR Holding Inc. must maintain an interest coverage ratio,
defined as the ratio of Adjusted EBITDA to cash interest
expense, of 2.50 or greater on the last day of any fiscal
quarter. |
Based upon Adjusted EBITDA (as defined in the new credit
agreement), Alpha NR Holding Inc.s leverage ratio and
interest coverage ratio (as such ratios are defined in the new
credit agreement), calculated on a pro forma basis giving effect
to the Nicewonder Acquisition and the 2005 Financing, would have
been 2.41 and 5.78, respectively. As in the prior credit
facility, Adjusted EBITDA will be used to determine compliance
with many of the covenants under the new credit facility. A
breach of the covenants in the new credit facility that are tied
to ratios based on Adjusted EBITDA could result in a default
under the new credit facility and the lenders could elect to
declare all amounts borrowed due and payable. Any acceleration
under our new credit facility would also result in a default
under our indenture.
76
Adjusted EBITDA is defined in our prior credit facility (as well
as in our new credit facility) as EBITDA further adjusted to
exclude non-recurring items, non-cash items and other
adjustments permitted in calculating covenant compliance under
our prior credit facility, as shown in the table below. We
believe that the inclusion of supplementary adjustments to
EBITDA applied in presenting Adjusted EBITDA is appropriate to
provide additional information to investors to demonstrate
compliance with our financial covenants.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Three Months | |
|
Three Months | |
|
Three Months | |
|
Twelve Months | |
|
|
Ended | |
|
Ended | |
|
Ended | |
|
Ended | |
|
Ended | |
|
|
December 31, | |
|
March 31, | |
|
June 30, | |
|
September 30, | |
|
September 30, | |
|
|
2004 | |
|
2005 | |
|
2005 | |
|
2005 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands) | |
Net income (loss)
|
|
$ |
1,115 |
|
|
$ |
(25,801 |
) |
|
$ |
26,393 |
|
|
$ |
8,210 |
|
|
$ |
9,917 |
|
Interest expense, net
|
|
|
5,344 |
|
|
|
5,830 |
|
|
|
6,456 |
|
|
|
6,439 |
|
|
|
24,069 |
|
Income tax expense (benefit)
|
|
|
(772 |
) |
|
|
2,324 |
|
|
|
9,182 |
|
|
|
3,542 |
|
|
|
14,276 |
|
Depreciation, depletion and amortization expenses
|
|
|
16,660 |
|
|
|
14,480 |
|
|
|
15,048 |
|
|
|
16,277 |
|
|
|
62,465 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
|
22,347 |
|
|
|
(3,167 |
) |
|
|
57,079 |
|
|
|
34,468 |
|
|
|
110,727 |
|
Minority interest(1)
|
|
|
268 |
|
|
|
2,846 |
|
|
|
|
|
|
|
|
|
|
|
3,114 |
|
Stock-based compensation charge(2)
|
|
|
|
|
|
|
36,407 |
|
|
|
3,381 |
|
|
|
3,381 |
|
|
|
43,169 |
|
Asset impairment charge and write-offs(2)
|
|
|
|
|
|
|
|
|
|
|
683 |
|
|
|
|
|
|
|
683 |
|
Alpha Natural Resources, Inc. (income) expense(2)
|
|
|
|
|
|
|
209 |
|
|
|
(505 |
) |
|
|
|
|
|
|
(296 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA
|
|
$ |
22,615 |
|
|
$ |
36,295 |
|
|
$ |
60,638 |
|
|
$ |
37,849 |
|
|
$ |
157,397 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Leverage ratio(3)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1.66 |
|
Interest coverage ratio(4)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8.80 |
|
|
|
(1) |
Because our prior credit facility and our senior notes are
issued by our subsidiaries, we are required to adjust our EBITDA
for our minority interest which does not exist at the subsidiary
level. |
|
(2) |
Adjusted EBITDA as defined in our prior credit facility is
adjusted to add back for the non-cash portion of the stock-based
compensation charge related to our Internal Restructuring and
initial public offering as recorded by Alpha Natural Resources,
LLC, for the asset impairment charge related to our NKC
operations, for other asset write-offs and amounts of income or
expense related to the parent of Alpha Natural Resources, LLC.
Income or expenses related solely to Alpha Natural Resources,
Inc. are excluded from the calculation of Adjusted EBITDA under
our prior credit agreement. |
|
(3) |
Leverage ratio is defined in our prior credit facility as total
debt divided by Adjusted EBITDA. |
|
(4) |
Interest coverage ratio is defined in our prior credit facility
as Adjusted EBITDA divided by cash interest expense. |
77
Contractual Obligations
The following is a summary of our significant contractual
obligations as of December 31, 2004 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 | |
|
2006-2007 | |
|
2008-2009 | |
|
After 2009 | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Long-term debt and capital leases(1)
|
|
$ |
1,693 |
|
|
$ |
1,236 |
|
|
$ |
8,548 |
|
|
$ |
175,000 |
|
|
$ |
186,477 |
|
Equipment purchases
|
|
|
43,271 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
43,271 |
|
Operating leases
|
|
|
4,307 |
|
|
|
6,463 |
|
|
|
769 |
|
|
|
261 |
|
|
|
11,800 |
|
Minimum royalties
|
|
|
9,212 |
|
|
|
17,368 |
|
|
|
15,509 |
|
|
|
30,031 |
|
|
|
72,120 |
|
Coal purchases
|
|
|
342,422 |
|
|
|
110,463 |
|
|
|
|
|
|
|
|
|
|
|
452,885 |
|
Coal contract buyout
|
|
|
680 |
|
|
|
1,360 |
|
|
|
1,360 |
|
|
|
567 |
|
|
|
3,967 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
401,585 |
|
|
$ |
136,890 |
|
|
$ |
26,186 |
|
|
$ |
205,859 |
|
|
$ |
770,520 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Long-term debt and capital leases include principal amounts due
in the years shown. Interest payable on these obligations,
assuming a rate of 7.0% on our variable rate loan, would be
approximately $18.3 million in 2005, $36.4 million in
2006 to 2007, $35.8 million in 2008 to 2009, and
$42.3 million after 2009. |
Additionally, we have long-term liabilities relating to mine
reclamation and end-of-mine closure costs, workers
compensation benefits and all of our operating and
management-services subsidiaries have long-term liabilities
relating to retiree health care (postretirement benefits). The
table below reflects the estimated undiscounted payments of
these obligations as of December 31, 2004 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 | |
|
2006-2007 | |
|
2008-2009 | |
|
After 2009 | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Reclamation
|
|
$ |
6,691 |
|
|
$ |
11,062 |
|
|
$ |
8,473 |
|
|
$ |
34,209 |
|
|
$ |
60,435 |
|
Postretirement
|
|
|
39 |
|
|
|
193 |
|
|
|
1,078 |
|
|
|
155,365 |
|
|
|
156,675 |
|
Workers compensation benefits
|
|
|
1,612 |
|
|
|
2,235 |
|
|
|
324 |
|
|
|
2,119 |
|
|
|
6,290 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
8,342 |
|
|
$ |
13,490 |
|
|
$ |
9,875 |
|
|
$ |
191,693 |
|
|
$ |
223,400 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Off-Balance Sheet Arrangements
In the normal course of business, we are a party to certain
off-balance sheet arrangements. These arrangements include
guarantees and financial instruments with off-balance sheet
risk, such as bank letters of credit and performance or surety
bonds. No liabilities related to these arrangements are
reflected in our combined balance sheets, and we do not expect
any material adverse effects on our financial condition, results
of operations or cash flows to result from these off-balance
sheet arrangements.
From time to time, we provide guarantees to financial
institutions to facilitate the acquisition of mining equipment
by third parties who mine coal for us. This arrangement is
beneficial to us because it helps insure a continuing source of
coal production.
Federal and state laws require us to secure payment of certain
long-term obligations such as mine closure and reclamation
costs, federal and state workers compensation, coal leases
and other obligations. We typically secure these payment
obligations by using surety bonds, an off-balance sheet
instrument. The use of surety bonds is less expensive for us
than the alternative of posting a 100% cash bond or a bank
letter of credit, either of which would require a greater use of
our credit facility. We then use bank letters of credit to
secure our surety bonding obligations as a lower cost
alternative than securing those bonds with cash. Under our
$150.0 million committed bonding facility, we are required
to provide bank letters of credit in an amount up to 50% of the
aggregate bond liability. Recently, surety bond costs have
increased, while the market terms of surety bonds have generally
become less favorable to us. To the extent that surety bonds
become unavailable, we would seek to secure our reclamation
obligations with letters of credit, cash deposits or other
suitable forms of collateral.
78
As of September 30, 2005, we had outstanding surety bonds
with third parties for post-mining reclamation totaling
$88.9 million plus $8.6 million for miscellaneous
purposes. We maintained letters of credit as of
September 30, 2005 totaling $53.0 million to secure
reclamation and other obligations. As of September 30, 2005, on
a pro forma basis giving effect to the Nicewonder Acquisition
and 2005 Financing, we would have had outstanding surety bonds
with third parties for post-mining reclamation totaling
$112.6 million plus $8.6 million for miscellaneous
purposes, and letters of credit totaling $65.5 million to
secure such reclamation and other obligations.
In connection with our acquisition of Coastal Coal Company, the
seller, El Paso CGP Company, agreed to retain and indemnify
us for all workers compensation and black lung claims
incurred prior to the acquisition date of January 31, 2003.
The majority of this liability relates to claims in the state of
West Virginia. If El Paso CGP Company fails to honor its
agreement with us, then we would be liable for the payment of
those claims, which were estimated in April 2004 to be
approximately $5.4 million on an undiscounted basis using
claims data through June 2003. El Paso CGP Company has
posted a bond with the state of West Virginia for the required
discounted amount of $3.7 million for claims incurred prior
to the acquisition.
Critical Accounting Estimates and Assumptions
Our discussion and analysis of our financial condition, results
of operations, liquidity and capital resources is based upon our
combined financial statements, which have been prepared in
accordance with U.S. generally accepted accounting
principles (GAAP). GAAP requires that we 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 ongoing
basis, we evaluate our estimates. We base our estimates on
historical experience and on various other assumptions that we
believe are 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.
Reclamation. Our 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. We account for the costs of our reclamation activities in
accordance with the provisions of SFAS No. 143,
Accounting for Asset Retirement Obligations.
We determine the future cash flows necessary to satisfy our
reclamation obligations on a mine-by-mine basis based upon
current permit requirements and various estimates and
assumptions, including estimates of disturbed acreage, cost
estimates, and assumptions regarding productivity. Estimates of
disturbed acreage are determined based on approved mining plans
and related engineering data. Cost estimates are based upon
third-party costs. Productivity assumptions are based on
historical experience with the equipment that is expected to be
utilized in the reclamation activities. In accordance with the
provisions of SFAS No. 143, we determine the fair
value of our asset retirement obligations. In order to determine
fair value, we must also estimate a discount rate and
third-party margin. Each is discussed further below:
|
|
|
|
|
Discount Rate. SFAS No. 143 requires that asset
retirement obligations be recorded at fair value. In accordance
with the provisions of SFAS No. 143, we utilize
discounted cash flow techniques to estimate the fair value of
our obligations. We base our discount rate on the rates of
treasury bonds with maturities similar to expected mine lives,
adjusted for our credit standing. |
|
|
|
Third-Party Margin. SFAS No. 143 requires the
measurement of an obligation to be based upon the amount a third
party would demand to assume the obligation. Because we plan to
perform a significant amount of the reclamation activities with
internal resources, a third-party margin was added to the
estimated costs of these activities. This margin was estimated
based upon our historical experience with contractors performing
certain types of reclamation activities. The inclusion of this
margin will result in a recorded obligation that is greater than
our estimates of our |
79
|
|
|
|
|
cost to perform the reclamation activities. If our cost
estimates are accurate, the excess of the recorded obligation
over the cost incurred to perform the work will be recorded as a
gain at the time that reclamation work is completed. |
On at least an annual basis, we review our entire reclamation
liability and make necessary adjustments for permit changes as
granted by state authorities, additional costs resulting from
accelerated mine closures, and revisions to cost estimates and
productivity assumptions, to reflect current experience. At
September 30, 2005, we had recorded asset retirement
obligation liabilities of $41.0 million, including amounts
reported as current. While the precise amount of these future
costs cannot be determined with certainty, as of
September 30, 2005, we estimate that the aggregate
undiscounted cost of final mine closure is approximately
$58.3 million.
Coal Reserves. There are numerous uncertainties inherent
in estimating quantities of economically recoverable coal
reserves. Many of these uncertainties are beyond our control. As
a result, estimates of economically recoverable coal reserves
are by their nature uncertain. Information about our reserves
consists of estimates based on engineering, economic and
geological data assembled by our internal engineers and
geologists and reviewed by a third-party consultant. Some of the
factors and assumptions that impact economically recoverable
reserve estimates include:
|
|
|
|
|
geological conditions; |
|
|
|
historical production from the area compared with production
from other producing areas; |
|
|
|
the assumed effects of regulations and taxes by governmental
agencies; |
|
|
|
assumptions governing future prices; and |
|
|
|
future operating costs. |
Each of these factors may in fact vary considerably from the
assumptions used in estimating reserves. For these reasons,
estimates of the economically recoverable quantities of coal
attributable to a particular group of properties, and
classifications of these reserves based on risk of recovery and
estimates of future net cash flows, may vary substantially.
Actual production, revenues and expenditures with respect to
reserves will likely vary from estimates, and these variances
may be material.
Postretirement Medical Benefits. Three of our
subsidiaries have long-term liabilities for postretirement
benefit cost obligations. Detailed information related to these
liabilities is included in the notes to our combined financial
statements included elsewhere in this prospectus. Liabilities
for postretirement benefit costs are not funded. The liability
is actuarially determined, and we use various actuarial
assumptions, including the discount rate and future cost trends,
to estimate the costs and obligations for postretirement benefit
costs. The discount rate assumption reflects the rates available
on high quality fixed income debt instruments. The discount rate
used to determine the net periodic benefit cost for
postretirement benefits other than pensions was 6.25% for the
year ended December 31, 2004 and 6.75% for the year ended
December 31, 2003. We make assumptions related to future
trends for medical care costs in the estimates of retiree health
care and work-related injury and illness obligations. If our
assumptions do not materialize as expected, actual cash
expenditures and costs that we incur could differ materially
from our current estimates. Moreover, regulatory changes could
increase our requirement to satisfy these or additional
obligations.
Effective July 1, 2004, we began offering postretirement
medical benefits to most of our active employees that will
provide a credit equal to $20 per month per year of service
for pre-65 year-old retirees, and $9 per month per
year of service for post-65-year old retirees toward the
purchase of medical benefits (as defined) from us. This new plan
resulted in prior service cost of $27.1 million which will
be amortized over the remaining service lives of the employees
covered by this plan. This amortization of prior service cost is
expected to be approximately $2.8 million per year. We
recorded $3.7 million and $5.9 million in costs with
respect to this new plan in 2004 and the first nine months of
2005, respectively, consisting primarily of service cost,
amortization of prior service cost and interest cost.
80
Workers Compensation. Workers compensation is
a system by which individuals who sustain personal injuries due
to job-related accidents are compensated for their disabilities,
medical costs, and on some occasions, for the costs of their
rehabilitation, and by which the survivors of workers who suffer
fatal injuries receive compensation for lost financial support.
The workers compensation laws are administered by state
agencies with each state having its own set of rules and
regulations regarding compensation that is owed to an employee
who is injured in the course of employment. Our operations are
covered through a combination of a self-insurance program,
participation in a state run program, and an insurance policy.
We accrue for any self-insured liability by recognizing costs
when it is probable that a covered liability has been incurred
and the cost can be reasonably estimated. Our estimates of these
costs are adjusted based upon actuarial studies. Actual losses
may differ from these estimates, which could increase or
decrease our costs.
Coal Workers Pneumoconiosis. We are responsible
under various federal statutes, including the Coal Mine Health
and Safety Act of 1969, and various states statutes, for
the payment of medical and disability benefits to eligible
employees resulting from occurrences of coal workers
pneumoconiosis disease (black lung). Our operations are covered
through a combination of a self-insurance program, in which we
are a participant in a state run program, and an insurance
policy. We accrue for any self-insured liability by recognizing
costs when it is probable that a covered liability has been
incurred and the cost can be reasonably estimated. Our estimates
of these costs are adjusted based upon actuarial studies. Actual
losses may differ from these estimates, which could increase or
decrease our costs.
Income Taxes. We account for income taxes in accordance
with SFAS No. 109, Accounting for Income
Taxes, which requires the recognition of deferred tax
assets and liabilities using enacted tax rates for the effect of
temporary differences between the book and tax bases of recorded
assets and liabilities. SFAS No. 109 also requires
that deferred tax assets be reduced by a valuation allowance if
it is more likely than not that some portion or all of the
deferred tax asset will not be realized. In evaluating the need
for a valuation allowance, we take into account various factors
including the expected level of future taxable income and
available tax planning strategies. If future taxable income is
lower than expected or if expected tax planning strategies are
not available as anticipated, we may record a change to the
valuation allowance through income tax expense in the period the
determination is made.
New Accounting Pronouncements
In November 2004, the Financial Accounting Standards Board (the
FASB) issued SFAS No. 151, Inventory Costs,
which amends the guidance in Accounting Research Bulletin
(ARB) No. 43, Chapter 4, Inventory
Pricing, to clarify the accounting for abnormal amounts of
idle facility expense, freight, handling costs, and wasted
material (spoilage). SFAS No. 151 clarifies that
abnormal amounts of idle facility expense, freight, handling
costs, and wasted materials (spoilage) should be recognized
as current-period charges instead of inventory costs. The
provisions of this pronouncement will be effective for inventory
costs incurred during fiscal years ending after June 15,
2005. We are currently evaluating whether the adoption of
SFAS No. 151 will have any material financial
statement impact.
In December 2004, the FASB issued SFAS No. 123(R),
Share-Based Payment, which requires companies to expense
the fair value of equity awards over the required service
period. This Statement is a revision of SFAS No. 123,
Accounting for Stock-Based Compensation.
SFAS No. 123(R) supersedes APB Opinion No. 25,
Accounting for Stock Issued to Employees, which uses the
intrinsic value method to value stock-based compensation. On
April 14, 2005, the SEC adopted a new rule that amends the
effective date of SFAS No. 123(R) to allow SEC
registrants to implement SFAS No. 123(R) as of the
beginning of the first annual reporting period that begins after
June 15, 2005. This ruling by the SEC changes the effective
date under SFAS No. 123(R) that would have required
SEC registrants to adopt SFAS No. 123(R) at the
beginning of their next interim or annual reporting period that
begins after June 15, 2005. There are various methods of
adopting SFAS 123(R), and we have not yet determined what
method we will use or if we will adopt SFAS No. 123(R)
in an earlier period than is required.
In December 2004, the FASB issued SFAS No. 153,
Exchanges of Nonmonetary Assets, an amendment of APB Opinion
No. 29, Accounting for Nonmonetary Transactions. This
Statements
81
amendments are based on the principle that exchanges of
nonmonetary assets should be measured based on the fair value of
the assets exchanged. Further, SFAS No. 153 eliminates
the narrow exception for nonmonetary exchanges of similar
productive assets and replaces it with a broader exception for
exchanges of nonmonetary assets that do not have commercial
substance. The provisions of this pronouncement will be
effective for nonmonetary asset exchanges occurring in fiscal
periods beginning after June 15, 2005. We do not expect the
adoption of SFAS No. 153 to have any material impact
on our financial statements.
On March 17, 2005, the Emerging Issues Task Force
(EITF) of FASB reached consensus on EITF Issue
No. 04-6, Accounting for Stripping Costs Incurred during
Production in the Mining Industry, and on March 30,
2005, the FASB Board ratified the consensus. The EITF reached
consensus that stripping costs incurred during the production
phase of a mine are variable production costs that should be
included in the costs of inventory produced during the period
that the stripping costs are incurred. ETIF 04-6 is effective
for the first reporting period in fiscal years beginning after
December 15, 2005 with early adoption permitted. The
Company does not expect that the adoption of
EITF 04-6 will
have any material financial statement impact.
In March 2005, the FASB issued Interpretation No. 47,
Accounting for Conditional Asset Retirement Obligations,
an interpretation of SFAS No. 143, Accounting for
Asset Retirement Obligations. This Interpretation clarifies
that an entity is required to recognize a liability for the fair
value of a conditional asset retirement obligation when incurred
if the liabilitys fair value can be reasonably estimated.
The provisions of this pronouncement are effective for fiscal
years ending after December 15, 2005. The Company does not
expect the adoption of Interpretation No. 47 will have any
material financial statement impact.
Discussion of Seasonality Impacts on Operations
Our business is seasonal, with operating results varying from
quarter to quarter. We have historically experienced lower sales
during winter months primarily due to the freezing of lakes that
we use to transport coal to some of our customers. As a result,
our first quarter cash flow and profits have been, and may
continue to be, negatively impacted. Lower than expected sales
by us during this period could have a material adverse effect on
the timing of our cash flows and therefore our ability to
service our obligations with respect to our existing and future
indebtedness.
Quantitative and Qualitative Disclosures about Market Risk
In addition to risks inherent in operations, we are exposed to
market risks. The following discussion provides additional
detail regarding our exposure to the risks of changing coal
prices, interest rates and customer credit.
We are exposed to market price risk in the normal course of
selling coal. As of December 31, 2005, approximately 12%,
54% and 77%, respectively, of our planned production for 2006,
2007 and 2008, including production from operations we acquired
in the Nicewonder Acquisition, was uncommitted and was not yet
priced. Compared to prior years, we have increased the
proportion of our planned future production in 2006 and 2007 for
which we have contracts to sell coal, which has the effect of
lessening our market price risk.
All of our borrowings under the revolving credit facility are at
a variable rate, so we are exposed to rising interest rates in
the United States. A one percentage point increase in interest
rates would result in an annualized increase to interest expense
of approximately $0.8 million based on our variable rate
borrowings as of September 30, 2005, or $3.1 million
based on our variable rate borrowings as of September 30,
2005 calculated on a pro forma basis giving effect to the
Nicewonder Acquisition and 2005 Financing.
Our concentration of credit risk is substantially with electric
utilities, producers of steel and foreign customers. Our policy
is to independently evaluate a customers creditworthiness
prior to entering into transactions and to periodically monitor
the credit extended.
82
THE COAL INDUSTRY
Coal is a major contributor to the world energy supply. In 2004,
coal represented approximately 27% of the worlds primary
energy consumption and was also the fastest growing energy
source in the world, according to BP Statistical Review.
The primary use for coal is to fuel electric power generation.
In 2004, coal generated 51.5% of the electricity produced in the
United States, according to the EIA.
The United States is the second largest coal producer in the
world, exceeded only by China, according to BP Statistical
Review. Other leading coal producers include Australia, India,
South Africa and Russia. According to BP Statistical
Review, the United States is the largest holder of coal reserves
in the world, with approximately 245 years of supply at
current production rates. U.S. coal reserves are more
plentiful than oil or natural gas, with coal representing
approximately 93% of the nations fossil fuel reserves on a
Btu-comparable basis according to data collected by
BP Statistical Review.
U.S. Coal Production Regions
According to the EIA, U.S. coal production has increased by
82% during the last 30 years. In 2004, total U.S. coal
production, according to the EIA, was 1.1 billion tons. The
Powder River Basin accounted for 39% of the total volume of
U.S. coal production in 2003, with Central Appalachia
accounting for 21%, the Midwest accounting for 13%, the West
(other than the Powder River Basin) accounting for 12%, Northern
Appalachia accounting for 12% and Southern Appalachia accounting
for 2%, according to Platts. After the sale of NKC on
April 14, 2005, all of our coal production comes from the
Central and Northern Appalachian regions.
Central Appalachia, including eastern Kentucky, Virginia and
southern West Virginia, is the second largest coal producing
region in the United States (21% of 2004 production). Coal from
this region generally has a high heat content of between 12,000
and 14,000 Btus per pound and a low sulfur content ranging from
0.7% to 1.5%. From 2001 to 2004, according to Platts, the
Central Appalachian region experienced a decline in production
from 266.4 million tons to 229.2 million tons, or a
14% decline, primarily as a result of the depletion of
economically attractive reserves, permitting issues and
increasing costs of production, which was partially offset by
production increases in Southern West Virginia due to the
expansion of more economically attractive surface mines. The EIA
estimates that Central Appalachian operators marketed
approximately 52% of their 2003 coal sales directly to electric
generators, principally in the southeastern U.S., 25% to coal
synfuel plants that further process the coal for sale to
electric generators and industrial end-users, and the remainder
primarily to steel producers in the U.S. and internationally.
Central Appalachia is the primary source of U.S. coal
exports. As of November 1, 2005, we operate or have the
right to receive production from 50 mines in this region
producing primarily high Btu, low sulfur steam and metallurgical
coal.
Northern Appalachia, including Maryland, Ohio, Pennsylvania and
northern West Virginia, is the other major coal producing region
in the eastern U.S. (12% of 2004 U.S. production).
Coal from this region generally has a high heat content of
between 12,000 and 14,000 Btus per pound with typical sulfur
content ranging from 1.0% to 4.5%. From 2001 to 2004, according
to Platts, the Northern Appalachian region experienced a decline
in production from 142.3 million tons to 135 million
tons, or a 5% decline, primarily as a result of production
problems at longwall mining operations in southern Pennsylvania
and northern West Virginia. Northern Appalachian operators
market the vast majority of their coal to electric generators.
Despite its sulfur content, which is considered medium sulfur
coal, coal from Northern Appalachia is generally considered
attractive to electricity generators because of its high average
heat content of approximately 13,000 Btus per pound. As of
November 1, 2005, we operate or have the right to receive
production from 19 mines in this region producing primarily
steam and metallurgical coal with a sulfur content of greater
than 1.5% that has an average heat content of approximately
12,350 Btus per pound.
We do not currently operate any mines in the Powder River Basin,
the Midwest region, Southern Appalachia or the Four Corners
region.
83
Demand for U.S. Coal Production
Coal produced in the United States is primarily consumed
domestically by utilities to generate electricity, by steel
companies to produce coke for use in blast furnaces, and by a
variety of industrial users to heat and power foundries, cement
plants, paper mills, chemical plants and other manufacturing and
processing facilities. According to the EIA, 98% of coal
consumed in the United States in 2004 was from domestic
production sources. Coal produced in the United States is also
exported, primarily from east coast terminals. The breakdown of
2004 U.S. coal consumption by end user, as estimated by the
EIA, is as follows:
|
|
|
|
|
|
|
|
|
|
End Use |
|
Tons | |
|
% of Total | |
|
|
| |
|
| |
|
|
(In millions) | |
Electrical generation
|
|
|
1,015.1 |
|
|
|
88 |
% |
Industrial, residential & commercial
|
|
|
65.4 |
|
|
|
6 |
% |
Steel making
|
|
|
23.7 |
|
|
|
2 |
% |
|
|
|
|
|
|
|
|
Total domestic(1)
|
|
|
1,104.3 |
|
|
|
96 |
% |
Exports
|
|
|
48.0 |
|
|
|
4 |
% |
|
|
|
|
|
|
|
|
Total
|
|
|
1,152.3 |
|
|
|
100 |
% |
|
|
|
|
|
|
|
|
|
(1) |
Includes consumption of 27.3 million tons of coal imported
into the United States in 2004. |
As reflected in the above table, the dominant use for coal in
the United States is for electricity generation. Coal used as
fuel to generate electricity and for use by industrial consumers
is commonly referred to as steam coal, and it
accounted for approximately 63% of our 2004 coal sales volume.
Coal has long been favored as an electricity generating fuel by
regulated utilities because of its low cost compared to other
fuels. The largest cost component in electricity generation is
fuel. This fuel cost is typically lower for coal than competing
hydrocarbon-based fuels such as oil and natural gas on a
Btu-comparable basis. Global Energy Advisors has estimated the
average total production costs of electricity, using coal and
competing generation alternatives in the first quarter of 2005
as follows:
|
|
|
|
|
|
|
Cost per | |
|
|
Megawatt | |
Electrical Generation Type |
|
Hour | |
|
|
| |
Natural Gas
|
|
$ |
59.14 |
|
Oil
|
|
|
57.18 |
|
Coal
|
|
|
19.41 |
|
Nuclear
|
|
|
16.35 |
|
Hydroelectric
|
|
|
7.45 |
|
Factors other than fuel cost that influence each utilitys
choice of the type of electricity generation include, among
others, facility construction cost, access to fuel
transportation infrastructure and environmental restrictions.
The breakdown of U.S. electricity generation by fuel source
in 2004, according to EIA, is as follows:
|
|
|
|
|
|
|
|
% of Total | |
|
|
Electricity | |
Electricity Generation Source |
|
Generation | |
|
|
| |
Coal
|
|
|
51.5 |
% |
Nuclear
|
|
|
20.8 |
% |
Natural Gas
|
|
|
16.3 |
% |
Hydro
|
|
|
6.8 |
% |
Oil and Other
|
|
|
4.6 |
% |
|
|
|
|
|
Total
|
|
|
100.0 |
% |
|
|
|
|
84
The EIA projects that generators of electricity will increase
their demand for coal as demand for electricity increases.
Because coal-fired generation is used in most cases to meet
base load requirements, which are the minimum
amounts of electric power delivered or required over a given
period of time at a steady rate, coal consumption has generally
grown at the pace of electricity demand growth. Demand for
electricity has historically grown in proportion to
U.S. economic growth as measured by Gross Domestic Product.
Based on estimates compiled by the EIA, coal consumption is
expected to grow 1.6% per year until 2025.
The other major market for our coal is the steel industry. The
type of coal used in steel making is referred to as
metallurgical coal, and it accounted for
approximately 37% of our 2004 coal sales volume. When making
steel in an integrated steel mill, two of the key raw
ingredients are iron ore and coke. Coke is the substance formed
when metallurgical coal is heated in a coking oven to a very
high temperature in the absence of air. In the blast furnace of
an integrated steel mill, coke is primarily used to
(i) generate the heat required to convert iron ore into
molten iron; (ii) generate the reducing gas necessary to
chemically convert iron oxides into hot metal; and
(iii) create a permeable bed to allow the molten iron to
drip down and the reducing gases to rise up. Generally, 1.5 tons
of metallurgical coal produces approximately 1 ton of coke,
which in turn is needed to produce approximately 2 tons of steel.
Blast furnaces are designed to use specific grades of cokes, and
as a result, coking ovens are designed to use metallurgical
coals with specific qualities. Metallurgical coal is
distinguished by special quality characteristics that include
high carbon content, low expansion pressure, low sulfur content,
and various other chemical attributes. Metallurgical coal is
also high in heat content (as measured in Btus), and therefore
can alternatively be used by utilities as fuel for electricity
generation. Consequently, metallurgical coal producers have the
opportunity to select the market that provides maximum revenue.
The premium price offered for metallurgical coal by steel makers
for its coke-making attributes is typically higher than the
price offered by utility coal buyers that typically value only
the heat and sulfur content of steam coal.
U.S. metallurgical coal reserves are predominately
concentrated in the Central Appalachian region.
In 2004, approximately 4% of our coal sales were made to
industrial consumers, all of which was steam coal. Industrial
users of coal typically purchase high Btu products with the same
type of quality focus as utility coal buyers. The primary goal
is to maximize heat content, with other specifications like ash
content, sulfur content, and size varying considerably among
different customers. Because most industrial coal consumers use
considerably less tonnage than electric generating stations,
they typically prefer to purchase coal that is screened and
sized to specifications that streamline coal handling processes.
Due to the more stringent size and quality specifications,
industrial customers often pay a premium above utility coal
pricing.
Coal produced in the United States that is shipped for North
American consumption is typically sold at the mine loading
facility with transportation costs being borne by the purchaser.
Offshore export shipments are normally sold at the ship-loading
terminal, with the producer paying for the transportation costs
to the port and the purchaser paying the ocean freight.
While delivery to coal consumers often involves more than one
mode of transportation, according to the EIA, approximately
two-thirds of U.S. coal production is shipped via
railroads. In addition, coal is also shipped via trucks, barges,
overland conveyors, and ocean vessels loaded at export terminals.
The United States ranked sixth among worldwide exporters of coal
in 2004, according to estimates by the World Coal Institute.
Australia was the largest exporter, with other major exporters
including China, Indonesia, South Africa, Russia and Colombia.
According to the EIA, the United States continues to be a swing
supplier of coal in the world market. The EIAs most recent
estimates indicate that U.S. exports in 2004 decreased by
over 33% since 1994 as a result of increased international
competition, the U.S. dollars strength over time in
comparison to foreign currencies and the depletion of reserves
in regions of the United States that have traditionally sold
into the export market. According to the EIA, the United States
exported 48.0 million tons of coal in 2004, of which 56%
was used for electricity generation and 44% was used for steel
making. U.S. coal exports were shipped to 25 countries in
2003. According to the EIA, the largest purchaser of both
exported steam coal and exported metallurgical coal from the
United States in
85
2004 was Canada, which imported 14 million tons, or 66%, of
total steam coal exports and 3.8 million tons, or 14%, of
total metallurgical coal exports.
Industry Trends
In recent years, the U.S. coal industry has experienced
several significant trends including:
Growth in Coal Consumption. According to the EIA, from
1990 to 2004 coal consumption in the United States increased
from 904 million tons to 1,104.3 million tons, or 22%.
The largest driver of increased coal consumption during this
period was increased demand for electricity, as electricity
production by domestic electric power producers increased 31%
and coal consumption by electric power producers increased 30%.
As coal remains one of the lowest cost fuel sources for domestic
electric power producers, we believe coal consumption should
continue to expand as demand for electricity continues to
increase.
Increased Utilization of Excess Capacity at Existing
Coal-Fired Power Plants. We believe that existing coal-fired
plants will supply much of the near-term projected increase in
the demand for electricity because they possess excess capacity
that can be utilized at low incremental costs. In 2004, the
estimated average utilization of the existing coal-fired power
plant fleet was 72%, significantly below the estimated potential
utilization rate of 85%. If U.S. coal fueled plants operate
at utilization rates of 85%, we believe they would consume
approximately 185 million additional tons of coal per year,
which represents an increase of approximately 16% over current
coal consumption. In comparison, in 2004, the average
utilization of the existing nuclear-fired power plant fleet was
estimated by Platts to be 90%.
Construction of New Coal-Fired Power Plants. The NETL
projects that more than 100,000 megawatts of new coal-fired
electric generation capacity will be constructed in the United
States by 2025. The NETL has identified 124 coal-fired plants,
representing 73,000 megawatts of electric generation capacity,
which have been proposed and are currently in various stages of
development. The DOE projects that approximately 70 of these
proposed coal-fired plants, representing approximately 43,000
megawatts of electric generation capacity, will be completed and
begin consuming coal to produce electricity by the end of 2010.
Industry Consolidation. The U.S. coal industry has
experienced significant consolidation over the last
15 years. In 2004, the five largest coal producers
controlled over 51% of coal produced in the United States,
compared to just 35% in 1995 and 22% in 1990, according to
Platts. Weaker coal prices in the late 1990s forced many smaller
operators to sell or shut down their operations. In addition, a
number of large international oil and gas companies decided to
exit the domestic coal industry. Despite increased
consolidation, the industry still remains relatively fragmented
with more than 700 coal producers in the United States in 2004,
according to Platts.
Increasingly Stringent Air Quality Laws. The coal
industry has witnessed a shift in demand to low sulfur coal
production driven by regulatory restrictions on sulfur dioxide
emissions from coal-fired power plants. In 2000, Phase II
of the Clean Air Acts Acid Rain regulations tightened
sulfur dioxide restrictions to 1.2 pounds of sulfur dioxide
per million Btu. Sulfur dioxide and other emissions may be
restricted further by some currently proposed laws and
regulations. Currently, electric power generators operating
coal-fired plants can comply with these requirements by:
|
|
|
|
|
burning lower sulfur coal, either exclusively or mixed with
higher sulfur coal; |
|
|
|
installing pollution control devices, such as scrubbers, that
reduce the emissions from high sulfur coal; |
|
|
|
reducing electricity generating levels; or |
|
|
|
purchasing or trading emission credits to allow them to comply
with the sulfur dioxide emission compliance requirements. |
86
Additional current and proposed air emission requirements are
discussed in Environmental and Other Regulatory
Matters.
Recent Coal Market Conditions
According to traded coal indices and reference prices, U.S. and
international coal demand is currently strong. Coal pricing
increased in 2004 and has remained at historically high levels
since then in each of our coal production markets. We believe
that the current strong fundamentals in the U.S. coal
industry result primarily from:
|
|
|
|
|
stronger industrial demand following a recovery in the
U.S. manufacturing sector, evidenced by the most recent
estimate of 3.8% real GDP growth in the third quarter of 2005,
as reported by the Bureau of Economic Analysis; |
|
|
|
relatively low customer stockpiles, estimated by the EIA to be
approximately 105.6 million tons at the end of July, 2005,
down 5.8% from the same period in the prior year; |
|
|
|
declining coal production in Central Appalachia, including an
average annual decline of 4.9% in Central Appalachian coal
production volume from January 1, 2001 through
December 31, 2004; |
|
|
|
capacity constraints of U.S. nuclear-powered electricity
generators, which operated at an average utilization rate of
90.1% in 2004, up from 73.8% in 1994, as estimated by the EIA; |
|
|
|
|
high current and forward prices for natural gas and heating oil,
the primary fuels for electricity generation, with spot prices
as of January 5, 2006, for natural gas and heating oil at
$9.29 per million Btu and $1.76 per gallon,
respectively, as reported by Bloomberg L.P.; and |
|
|
|
|
increased international demand for U.S. coal for
steelmaking, driven by global economic growth, high ocean
freight rates and the weak U.S. dollar. |
Steam Coal Pricing. U.S. spot steam coal prices have
experienced significant volatility over the past few years.
Starting in late 2000 and continuing through mid-2001,
U.S. spot steam coal prices began to rise as a result of
reduced supply, higher demand from utility and industrial
consumers, and rising natural gas and oil prices. Beginning in
the middle of 2001, U.S. spot steam coal prices declined
due to the weakening domestic economy, higher utility consumer
inventories and increases in supply as the coal production
market reacted to the stronger prices during the late 2000/early
2001 period. Spot prices for U.S. steam coal remained
relatively low through the end of 2001 and during all of 2002.
U.S. spot steam coal prices have increased significantly
since mid-2003, particularly for coals sourced in the eastern
United States. The table below describes the percentage increase
in year-over-year average reference prices for coal as of
November 21, 2005, according to Platts, in the regions
where we produce our coal, and the percentage of our produced
and processed coal sales volume during 2004 by region:
|
|
|
|
|
|
|
|
|
|
|
Increase in Average | |
|
Percentage of Produced and | |
|
|
Reference Prices | |
|
Processed Coal Sales in 2004 | |
|
|
| |
|
| |
Central Appalachia
|
|
|
8.5 |
% |
|
|
72.2 |
% |
Northern Appalachia
|
|
|
13.5 |
% |
|
|
27.8 |
% |
87
The following chart sets forth historical steam coal prices in
various U.S. markets computed on an average monthly basis
for the period from January 1, 1999 to November 21,
2005.
Metallurgical Coal Pricing. Metallurgical coal prices in
both the domestic and seaborne export markets have increased
significantly over the past two years due to tight supply and
strong global steel production. The price increase in the
U.S. metallurgical coal market is due in part to improved
stability in the U.S. steel industry, which has increased
domestic demand for metallurgical coal. The
U.S. flat-rolled steel industry has experienced several
mergers and acquisitions involving a number of companies
emerging from, and assets sold out of, Chapter 11
bankruptcy protection. Many of the companies or assets
previously in Chapter 11 have reduced or eliminated certain
of their costs and obligations associated with their steel
operations, including environmental, employee and retiree
benefit and other obligations. This reduction in industry
liabilities, together with the recent weakening of the
U.S. dollar, has helped U.S. steel companies become
more competitive with foreign steel producers.
Prices for U.S. metallurgical coal in foreign markets have
been supported by significant increases in demand for
metallurgical coal by foreign steel producers, driven by higher
steel production in Asia and the Pacific Rim, particularly in
China. According to the International Iron and Steel Institute,
global steel consumption increased by 8.8% during 2004 over the
2003 level, Chinese steel consumption increased approximately
11% in 2004 over 2003, and global apparent steel demand is
projected to have increased by 2.7% in 2005, with 2005 apparent
steel demand in China increasing by 10.3%. Increased prices have
also been supported by circumstances affecting the coal export
industry in China and Australia, the worlds two largest
coal exporters. In Australia, the worlds largest coal
exporter, metallurgical coal exports have been reduced by
operating disruptions at certain Australian metallurgical coal
mines and capacity constraints at major Australian shipping
ports. Chinas contribution to the world metallurgical coal
export market has been reduced by restrictions on its
metallurgical coal exports announced in late 2003 in order to
satisfy domestic demand. Asia-Pacific Rim consumption of
metallurgical coal continues to strain supply, with BHP
Billiton, a major Australian producer, reporting a 53% increase
in average realized metallurgical coal prices for fiscal year
2005 over the prior fiscal year, and Fording Canadian Coal
Trust, a major Canadian producer, reporting an increase of
approximately 83% in average metallurgical coal sales price for
the nine months ended September 30, 2005 over the same
period in 2004.
88
The table below describes average sale prices, according to
Platts, for low volatile metallurgical coal at the Hampton
Roads, Virginia export terminals, through which we ship the
great majority of our metallurgical coal exports and which
collectively constitute the highest volume export facility for
U.S. metallurgical coal production, and the percentage
increase or decrease in prices year-over-year:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percentage | |
|
|
Increase | |
Average Sale Prices per Ton for Low Volatile Metallurgical | |
|
(Decrease) | |
Coal at Hampton Roads, Virginia Export Terminals | |
|
Year-Over-Year | |
| |
|
| |
September 30, 2004
|
|
$ |
135.00 |
|
|
|
September 30, 2005 |
|
|
$ |
130.00 |
|
|
|
(4) |
% |
April 5, 2004
|
|
$ |
135.00 |
|
|
|
April 1, 2005 |
|
|
$ |
135.00 |
|
|
|
0 |
% |
January 12, 2004
|
|
$ |
71.50 |
|
|
|
January 3, 2005 |
|
|
$ |
137.50 |
|
|
|
92 |
% |
October 6, 2003
|
|
$ |
52.00 |
|
|
|
October 4, 2004 |
|
|
$ |
135.00 |
|
|
|
160 |
% |
89
BUSINESS
Overview
We are a leading Appalachian coal producer. Our reserves
primarily consist of high Btu, low sulfur steam coal that is
currently in high demand in U.S. coal markets and
metallurgical coal that is currently in high demand in both U.S.
and international coal markets. We produce, process and sell
steam and metallurgical coal from eight regional business units,
which, as of November 1, 2005, are supported by 44 active
underground mines, 25 active surface mines and 11 preparation
plants located throughout Virginia, West Virginia, Kentucky and
Pennsylvania. We are also actively involved in the purchase and
resale of coal mined by others, the majority of which we blend
with coal produced from our mines, allowing us to realize a
higher overall margin for the blended product than we would be
able to achieve selling these coals separately.
Steam coal, which is primarily purchased by large utilities and
industrial customers as fuel for electricity generation,
accounted for approximately 62% of our coal sales volume in the
first nine months of 2005 and 63% of our 2004 coal sales volume.
The majority of our steam coal sales volume in the first nine
months of 2005 and during 2004 consisted of high Btu (above
12,500 Btu content per pound), low sulfur (sulfur content of
1.5% or less) coal, which typically sells at a premium to
lower-Btu, higher-sulfur steam coal. Metallurgical coal, which
is used primarily to make coke, a key component in the steel
making process, accounted for approximately 38% of our coal
sales volume in the first nine months of 2005 and 37% of our
2004 coal sales volume. Metallurgical coal generally sells at a
premium over steam coal because of its higher quality and its
value in the steelmaking process as the raw material for coke.
Under current market conditions, we are able to market a
significant portion of our higher quality steam coal as
metallurgical coal.
As discussed in note 22 to our financial statements, we
have one reportable segment Coal
Operations which consists of our coal extracting,
processing and marketing operations, as well as our purchased
coal sales function and certain other coal-related activities.
Our equipment and part sales and equipment repairs operations,
terminal services, coal and environmental analysis services and
leasing of mineral rights described below under
Other Operations are not included in our
Coal Operations segment.
History
On December 13, 2002, the First Reserve Stockholders, who
then owned 100% of the membership interests of ANR Holdings,
acquired the majority of the Virginia coal operations of our
Predecessor through wholly owned subsidiaries of ANR Holdings
for $62.9 million.
On January 31, 2003, wholly owned subsidiaries of ANR
Holdings acquired Coastal Coal Company for $67.8 million,
and on March 11, 2003, ANR Holdings and its subsidiaries
acquired the U.S. coal production and marketing operations
of AMCI for $121.3 million. Of the consideration for the
U.S. AMCI acquisition, $69.0 million was provided in
the form of an approximate 44% membership interest in ANR
Holdings issued to the owners of AMCI, which together with the
issuances of an approximate 1% membership interest to Madison
Capital Funding, LLC and Alpha Coal Management reduced the First
Reserve Stockholders membership interest in ANR Holdings to
approximately 55%. On November 17, 2003, we acquired the
assets of Mears for $38.0 million.
On April 1, 2004, we acquired substantially all of the
assets of Moravian Run Reclamation Co., Inc. for five thousand
dollars in cash and the assumption by us of certain liabilities,
including four active surface mines and two additional surface
mines under development, operating in close proximity to and
serving many of the same customers as our AMFIRE business unit
located in Pennsylvania. On May 10, 2004, we acquired a
coal preparation plant and railroad loading facility located in
Portage, Pennsylvania and related equipment and coal inventory
from Cooney Bros. Coal Company for $2.5 million in cash and
an adjacent coal refuse disposal site from a Cooney family trust
for $0.3 million in cash. On October 13, 2004, our
AMFIRE business unit entered into a coal mining lease with
Pristine Resources, Inc., a
90
subsidiary of International Steel Group Inc., for the right to
deep mine a substantial area of the Upper Freeport Seam in
Pennsylvania.
On February 11, 2005, we succeeded to the business and
became the indirect parent entity of ANR Holdings in connection
with the Internal Restructuring and, on February 18, 2005,
we completed an initial public offering of our common stock.
On April 14, 2005, we sold the assets of NKC to an
unrelated third party for cash in the amount of
$4.4 million, plus an amount in cash equal to the fair
market value of NKCs coal inventory, and the assumption by
the buyer of certain liabilities of NKC.
On October 26, 2005, we acquired the Nicewonder Coal
Groups coal reserves and operations in southern West
Virginia and southwestern Virginia for an aggregate purchase
price of $315.2 million, consisting of cash at closing in
the amount of $35.2 million, a cash tax payment of
$1.9 million to be made to the sellers in April 2006,
estimated transaction costs of $3.9 million,
$221.0 million principal amount of promissory installment
notes of one of our indirect, wholly owned subsidiaries, of
which $181.1 million was paid on November 2, 2005 and
$39.9 million is due on January 15, 2006, and
2,180,233 shares of our common stock valued at approximately
$53.2 million for accounting purposes. For this purpose,
the value of the common stock issued was based on the average
closing prices of our common stock for the five trading days
surrounding October 20, 2005, the date the number of shares
to be issued under the terms of the acquisition agreement became
fixed without subsequent revision. In connection with the
Nicewonder Acquisition, we also agreed to make royalty payments
to the former owners of the acquired companies in the amount of
$0.10 per ton of coal mined and sold from White Flame
Energys surface mine no. 10. The final cash purchase
price is subject to certain working capital and other
adjustments. The Nicewonder Acquisition consisted of the
purchase of the outstanding capital stock of White Flame Energy,
Inc., Twin Star Mining, Inc. and Nicewonder Contracting, Inc.,
the equity interests of Powers Shop, LLC and Buchanan Energy,
LLC and substantially all of the assets of Mate Creek Energy of
W. Va., Inc. and Virginia Energy Company, and the business of
Premium Energy, Inc. by merger. The operations we acquired from
the Nicewonder Coal Group constitute a new eighth business unit,
although we may eventually integrate these operations into our
seven other business units.
Competitive Strengths
We believe that the combination of the following competitive
strengths distinguishes us from our competitors.
We provide a comprehensive range of steam and metallurgical
coal products that are in high demand. Our reserves enable
us to provide customers with coal products that are in high
demand including high Btu, low sulfur steam coal,
and low, medium and high volatile metallurgical coal. Steam coal
customers value high Btu coal because it fuels electricity
generation more efficiently than lower energy content coal. In
addition, the demand for clean burning, low sulfur coal has
grown significantly since the implementation of sulfur emission
restrictions mandated by the Clean Air Act. Metallurgical coal
customers require precise coal characteristics to meet their
coke production specifications and generally value low volatile
metallurgical coal more highly than other categories of
metallurgical coal.
Our flexible mining operations and diversified asset base
allow us to manage costs while capitalizing on market
opportunities. Our 69 active mines, 11 preparation plants
and eight regional business units are supported by flexible and
cost-effective use of our mining equipment and personnel. Our
underground mines use the room and pillar mining method with
continuous mining equipment, and our surface mines principally
use trucks, loaders and dozers. Our mining equipment is
interchangeable and can be redirected easily at a relatively low
cost, providing us with flexibility to respond to changing
geologic, operating and market conditions. The diversity of our
portfolio of mines and preparation plants allows us to move
resources between existing or new operations and limits our mine
concentration risk. This diversity also limits our mine
concentration risk, as the mine that produced the greatest
amount of our coal contributed only approximately 10% of our
production during 2004.
91
Our ability to provide customized product offerings creates
valuable market opportunities, strengthens our customer
relationships and improves profitability. We have a
customer-focused marketing strategy that, combined
with our comprehensive range of coal product offerings and
established marketing network, enables us to customize our coal
deliveries to a customers precise needs and
specifications. The products we sell to our customers will often
be a blend of internally produced coal and coal we have
purchased from third parties, in contrast to the more
traditional approach of only offering coal produced from captive
mines. Our blending capabilities give us a competitive advantage
in product source and composition. We use spot market coal to
optimize the mix delivered to our customers and to maximize the
profitability of each of our contracts. We believe our
commitment to providing high quality coal products designed to
our customers specifications enables us to maintain strong
customer relationships while maximizing the value of our coal
reserves.
Our primary operating focus is the Appalachian region, the
region with the most producer-favorable coal supply and demand
dynamics in the United States. Our operations are focused on
Central and Northern Appalachia, which accounted for
approximately 72% and 28%, respectively, of the coal produced
from our mines during 2004. The Appalachian region has produced
declining supplies of coal in recent years while regional
demand, already the highest in the United States based on tons
consumed, is expected to increase due to growth in regional
demand for electricity. We believe these trends in Appalachian
coal supply and demand, the high quality of Appalachian coal and
the lower transportation costs that result from the proximity of
Appalachian producers and customers create favorable pricing
dynamics that provide us with an advantage over producers from
other regions.
Our Central Appalachian mining expertise provides us with
significant regional growth opportunities. Our focus on the
Appalachian region has allowed us to develop expertise in
efficiently mining Central Appalachian reserves. Furthermore, we
have developed both a good understanding of the regions
transportation infrastructure and a favorable reputation with
the regions property owners, coal industry operators and
employee base.
Our comparatively low amount of long-term reclamation and
employee-related liabilities provides us with financial
flexibility. As of September 30, 2005, on a pro forma
basis giving effect to the Nicewonder Acquisition, we had total
accrued reclamation liabilities of $48.9 million,
self-insured workers compensation liabilities of
$6.5 million and post-retirement obligations of
$22.2 million, and we had no pension liabilities and
minimal black lung liabilities. We believe the amount of these
liabilities are among the lowest of the publicly-traded
U.S. coal producers. In addition, because over 91% of our
approximately 3,240 employees are employed by our subsidiaries
on a union-free basis as of November 1, 2005, and
approximately 95% of our coal production during 2004 was
produced from mines operated by union-free employees, we are
better able to minimize the types of employee-related
liabilities commonly associated with union-represented mines.
Our management team has extensive coal industry experience
and has successfully integrated a number of acquisitions.
Our senior executives have, on average, more than 20 years
of experience in the coal industry, largely in the Appalachian
region, and they have substantial experience in increasing
productivity, reducing costs, implementing our marketing
strategy and coal blending capabilities, improving safety, and
developing and maintaining strong customer and employee
relationships. In addition to their operating strengths, the
majority of our senior executives have significant experience in
identifying, acquiring and integrating acquired coal companies
into existing organizations.
Business Strategy
We believe that we are well-positioned to enhance our position
as a leading Appalachian coal producer by continuing to
implement our strategy, which consists of the following key
components:
Achieve premium pricing and optimum efficiency in contract
fulfillment. We intend to continue to use our diversified
operating strategy, coal blending capabilities, market knowledge
and strong marketing organization to identify and capitalize on
opportunities to generate premium pricing for our coal and to
achieve optimum efficiency in fulfillment of coal contracts. As
of December 31, 2005, approximately 12%,
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54% and 77%, respectively, of our planned production for 2006,
2007 and 2008, including production from the operations we
acquired in the Nicewonder Acquisition, was uncommitted and was
not yet priced, which we believe provides us with significant
price certainty in the short-term while maintaining uncommitted
planned production that allows us to take an opportunistic
approach to selling our coal.
Maximize profitability of our mining operations. We
continuously reassess our reserves, mines and processing and
loading facilities in an effort to determine the optimum
operating configuration that maximizes our profitability,
efficient use of operating assets and return on invested
capital. We intend to continue to optimize the profitability of
our mining operations through a series of initiatives that
include:
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increasing production levels where we determine that such
increased production can be profitably achieved; |
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leveraging our product offerings, blending capabilities and
marketing organization to realize higher margins from our sales; |
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deploying our resources against the most profitable
opportunities available in our asset portfolio; |
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consolidating regional operations and increasing the utilization
of our existing preparation plants and loading facilities; |
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maintaining our focus on safety and implementing safety measures
designed to keep our workforce injury free; and |
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coordinating company-wide purchasing activities with major
vendors to provide materials and supplies at lower overall cost. |
Pursue strategic value-creating acquisitions. We have
successfully acquired and integrated businesses into our
operations, and we intend to continue to expand our business and
coal reserves through acquisitions of attractive, strategically
positioned assets. Although we intend to concentrate our efforts
in Appalachia, where we believe there remain attractive
acquisition opportunities, we will continue to evaluate
opportunities in other regions that meet our acquisition
criteria. We employ what we believe is a disciplined acquisition
strategy focused on acquiring coal and coal-related operations
and assets at attractive valuations. Some of the factors that we
consider in evaluating an acquisition candidate include:
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the candidates historical and projected financial
performance; |
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the quality and quantity of the candidates coal reserves,
coal processing facilities and other coal production assets; |
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the extent to which the geographic location of the
candidates coal reserves, processing facilities, and
access to transportation links and customers provides
synergistic opportunities with our existing operations and
assets; |
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the existing liabilities of the candidate, and whether the
acquisition can be completed in a manner that limits our
assumption of the candidates long-term liabilities; |
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in situations where we retain existing management, the
managements experience and relationship with the local
community; and |
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the experience, terms of employment and union status of the
candidates employees and the terms of the candidates
contracts with third-party mine and processing facility
operators. |
We believe that our recent acquisition of the Nicewonder Coal
Group is consistent with this strategy.
Maintain a strong safety, labor relations and environmental
record. One of our core values is protecting the health and
welfare of our employees by designing and implementing high
safety standards in the workplace. We also aim to preserve the
positive relationship we have developed with our employees.
There have been no material work stoppages at any of our
facilities since we were formed in 2002 or at any of our
Predecessor or acquired facilities in the past 10 years.
Furthermore, we aim to adhere to high standards in protecting
and preserving the environment in which we operate. For example,
in August 2004
93
we began implementing an environmental best practices system
across all of our subsidiaries operations that involves
the development of specific environmental policies and programs,
advanced training of our environmental staff and management, and
periodic assessments to measure the level of our environmental
awareness and compliance.
Mining Methods
We produce coal using two mining methods: underground
room and pillar mining using continuous mining equipment, and
surface mining, which are explained as follows:
Underground Mining. Underground mines in the United
States are typically operated using one of two different
methods: room and pillar mining or longwall mining. In 2004,
approximately 82% of our produced coal volume came from
underground mining operations using the room and pillar method
with continuous mining equipment. In room and pillar mining,
rooms are cut into the coal bed leaving a series of pillars, or
columns of coal, to help support the mine roof and control the
flow of air. Continuous mining equipment is used to cut the coal
from the mining face. Generally, openings are driven
20 feet wide and the pillars are generally rectangular in
shape measuring 35-50 feet wide by 35-80 feet long. As
mining advances, a grid-like pattern of entries and pillars is
formed. Shuttle cars are used to transport coal to the conveyor
belt for transport to the surface. When mining advances to the
end of a panel, retreat mining may begin. In retreat mining, as
much coal as is feasible is mined from the pillars that were
created in advancing the panel, allowing the roof to cave. When
retreat mining is completed to the mouth of the panel, the mined
panel is abandoned. The room and pillar method is often used to
mine smaller coal blocks or thin or non-contiguous seams, and
seam recovery ranges from 35% to 70%, with higher seam recovery
rates applicable where retreat mining is combined with room and
pillar mining. Productivity for continuous room and pillar
mining in the United States averages 3.5 tons per employee
per hour, according to the EIA.
The other underground mining method commonly used in the United
States is the longwall mining method, which we do not currently
use at any of our mines. In longwall mining, a rotating drum is
trammed mechanically across the face of coal, and a hydraulic
system supports the roof of the mine while it advances through
the coal. Chain conveyors then move the loosened coal to an
underground mine conveyor system for delivery to the surface.
Surface Mining. Surface mining is used when coal is found
close to the surface. In 2004, approximately 18% of our produced
coal volume (approximately 32% on a pro forma basis after giving
effect to the Nicewonder Acquisition) came from surface mines.
This method involves the removal of overburden (earth and rock
covering the coal) with heavy earth-moving equipment and
explosives, loading out the coal, replacing the overburden and
topsoil after the coal has been excavated and reestablishing
vegetation and plant life and making other improvements that
have local community and environmental benefit. Overburden is
typically removed at our mines by either hydraulic shovels or
front-end loaders which place the overburden into large trucks.
We also operate a fine coal recovery dredge operation which we
consider to be a surface mine. Seam recovery for surface mining
is typically 90% or more. Productivity depends on equipment,
geological composition and mining ratios and averages 4.8
tons per employee per hour in eastern regions of the United
States, according to the EIA.
Mining Operations
We have eight regional business units as of November 1,
2005, including the operations we acquired in the Nicewonder
Acquisition. As of November 1, 2005, these business units
include 11 preparation plants, each of which receive, blend,
process and ship coal that is produced from one or more of our
69 active mines (some of which are operated by third parties
under contracts with us), using two mining methods, underground
room and pillar and surface mining. Our underground mines
generally consist of one or more single or dual continuous miner
sections which are made up of the continuous miner, shuttle
cars, roof bolters and various ancillary equipment. Our surface
mines are a combination of mountain top removal, contour and
auger operations using truck/loader equipment fleets along with
large production
94
tractors. Most of our preparation plants are modern heavy media
plants that generally have both coarse and fine coal cleaning
circuits. We employ preventive maintenance and rebuild programs
to ensure that our equipment is modern and well-maintained.
During 2004 and the first nine months of 2005, most of our
preparation plants also processed coal that we purchased from
third-party producers before reselling it to our customers.
Within each regional business unit, mines have been developed at
strategic locations in close proximity to our preparation plants
and rail shipping facilities. Coal is transported from our
regional business units to customers by means of railroads,
trucks, barge lines and ocean-going vessels from terminal
facilities. The following table provides location and summary
information regarding our eight regional business units and the
preparation plants and active mines associated with these
business units as of November 1, 2005:
Regional Business Units
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Pro forma | |
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Number and Type of Mines as | |
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2004 | |
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of November 1, 2005 | |
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Production of | |
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Preparation Plant(s) as | |
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Saleable | |
Regional Business Unit |
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Location | |
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of November 1, 2005 | |
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Underground | |
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Surface | |
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Total | |
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Railroad | |
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Tons(1)(2) | |
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(In thousands) | |
Paramont
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Virginia |
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Toms Creek |
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9 |
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5 |
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14 |
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NS |
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5,876 |
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Dickenson-Russell
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Virginia |
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McClure River and Moss #3 |
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6 |
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1 |
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7 |
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CSX, NS |
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1,951 |
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Kingwood
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West Virginia |
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Whitetail |
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1 |
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0 |
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1 |
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CSX |
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1,862 |
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Brooks Run
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West Virginia |
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Erbacon |
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3 |
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1 |
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4 |
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CSX |
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1,987 |
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Welch
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West Virginia |
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Litwar, Kepler and Herndon |
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15 |
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0 |
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15 |
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NS |
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2,401 |
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AMFIRE
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Pennsylvania |
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Clymer and Portage |
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6 |
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12 |
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18 |
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NS |
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3,514 |
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Enterprise
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Kentucky |
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Roxana |
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4 |
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3 |
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7 |
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CSX |
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1,477 |
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Nicewonder
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Virginia and West Virginia |
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0 |
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3 |
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3 |
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NS |
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3,836 |
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Total |
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44 |
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25 |
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69 |
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22,904 |
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(1) |
Includes coal purchased from third-party producers that was
processed at our subsidiaries preparation plants in 2004. |
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(2) |
Excludes 457,000 tons of coal produced in 2004 by NKC. We sold
NKC on April 14, 2005. Includes production by our
Nicewonder business unit, which we acquired on October 26,
2005. |
CSX Railroad = CSX
Norfolk Southern Railroad = NS
The coal production and processing capacity of our mines and
processing plants is influenced by a number of factors including
reserve availability, labor availability, environmental permit
timing and preparation plant capacity. We have obtained permits
for and are currently in the process of developing Deep Mine 35
in Virginia to be operated by our Paramont business unit,
Madison deep mine in Pennsylvania which is operated by our
AMFIRE business unit, Seven Pines surface mine in West Virginia
which is operated by our Brooks Run business unit and Cucumber
deep mine in West Virginia to be operated by our Welch business
unit. We anticipate that we spent approximately
$60.0 million developing these mines during 2005. All four
of these new mines have begun production and we expect them to
reach full production capacity of approximately 2.8 million
tons by the end of 2006, some of which is intended to replace
existing production from contract-operated deep mines in
Virginia and West Virginia that are being depleted or
decommissioned. We expect the majority of this new production to
be metallurgical coal.
The following provides a brief description of our business units
as of November 1, 2005.
Paramont. Our Paramont business unit produces coal from
nine underground mines using continuous miners and the room and
pillar mining method. Two of the underground mines are operated
by independent contractors. The coal from these underground
mines is transported by truck to the Toms
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Creek preparation plant operated by Paramont, or the McClure
River or Moss #3 preparation plants operated by
Dickenson-Russell. At the preparation plant, the coal is
cleaned, blended and loaded onto rail for shipment to customers.
Paramont also operates five truck/loader surface mines. Three of
these surface mines are operated by independent contractors. The
coal produced by the surface mines is transported to one of our
preparation plants or raw coal loading docks where it is blended
and loaded onto rail for shipment to customers. During 2004,
Paramont purchased approximately 98,000 tons of coal from third
parties that was blended with Paramonts coal and shipped
to our customers. As of November 1, 2005, the Paramont
business unit was operating at a capacity to ship approximately
six million tons per year.
Dickenson-Russell. Our Dickenson-Russell business unit
produces coal from six underground mines using continuous miners
and the room and pillar mining method. Two of the underground
mines are operated by independent contractors. The coal from
these underground mines is transported by truck to the McClure
River or Moss #3 preparation plants operated by
Dickenson-Russell or the Toms Creek preparation plant operated
by Paramont where it is cleaned, blended and loaded on rail or
truck for shipment to customers. The Dickenson-Russell business
unit also operates a fine coal recovery dredge operation where
fine coals that were previously discarded by the coal cleaning
process are recovered, cleaned, and blended with other coals for
sale. During 2004, Dickenson-Russell purchased approximately
3,000 tons of coal from third parties that was blended with
Dickenson-Russells coal and shipped to our customers. As
of November 1, 2005, the Dickenson-Russell business unit
was operating at a capacity to ship approximately two million
tons per year.
Kingwood. Our Kingwood business unit produces coal from
one underground mine using continuous miners and the room and
pillar mining method. The Kingwood operation is staffed and
operated by Kingwood employees. The coal is belted to the
Whitetail preparation plant operated by Kingwood where it is
cleaned and loaded onto rail or truck for shipment to customers.
The Kingwood business unit has no surface mining operations.
During 2004, Kingwood purchased approximately 44,000 tons of
coal from third parties that was blended with Kingwoods
coal and shipped to our customers. As of November 1, 2005,
the Kingwood business unit was operating at a capacity to ship
approximately one and one-half million tons per year.
Brooks Run. Our Brooks Run business unit produces coal
from three underground mines using continuous miners and the
room and pillar mining method. All of the mining operations at
the Brooks Run business unit are staffed and operated by Brooks
Run employees. The coal is transported by truck to the Erbacon
preparation plant operated by Brooks Run where it is cleaned,
blended and loaded onto rail for shipment to customers. The
Brooks Run business unit has one surface mine operated with
Brooks Run employees. Brooks Run purchased no coal from third
parties in 2004. As of November 1, 2005, the Brooks Run
business unit was operating at a capacity to ship approximately
two and one-half million tons per year.
Welch. Our Welch business unit produces coal from fifteen
underground mines using continuous miners and the room and
pillar mining method. Three of the underground mines are
operated by our employees, and the others are operated by
independent contractors. The coal is transported by truck or
rail to the coal preparation plants operated by Welch where it
is cleaned, blended and loaded onto rail for shipment to
customers. The Welch business unit has no active surface mining
operations as of September 15, 2005. During 2004, the Welch
business unit purchased approximately 503,000 tons of coal from
third parties that was blended with other coals and shipped to
our customers. As of November 1, 2005, the Welch business
unit was operating at a capacity to ship approximately two and
three-quarter million tons per year.
AMFIRE. Our AMFIRE business unit produces coal from six
underground mines using continuous miners and the room and
pillar mining method. All of the underground mining operations
at AMFIRE are staffed and operated by AMFIRE employees. The
underground coal is delivered directly by truck to the customer,
or to the Clymer or Portage coal preparation plants or raw coal
loading docks where it is cleaned, blended and loaded onto rail
or truck for shipment to customers. AMFIRE also operates ten
truck/loader surface mines. Five of the surface mines are
operated by independent contractors. The surface
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mined coal is delivered directly by truck to the customer or
transported to the Clymer or Portage coal preparation plants or
raw coal loading docks where it is blended and loaded onto rail
or truck for shipment to customers. During 2004, AMFIRE
purchased approximately 175,000 tons of coal from third parties
that was blended with AMFIREs coal and shipped to our
customers. As of November 1, 2005, the AMFIRE business unit
was operating at a capacity to ship approximately four million
tons per year.
Enterprise. Our Enterprise business unit produces coal
from four underground mines using continuous miners and the room
and pillar mining method. All of the underground mining
operations at Enterprise are staffed and operated by Enterprise
employees. The coal from these underground mines is transported
by truck to the Roxana coal preparation plant operated by
Enterprise where it is cleaned, blended and loaded onto rail for
shipment to customers. Enterprise also has three truck/loader
surface mines which are operated by independent contractors. The
coal produced by the surface mines is transported to the Roxana
preparation plant where it is blended and loaded onto rail for
shipment to customers. During 2004, Enterprise purchased
approximately 52,000 tons of coal from third parties that was
blended with Enterprises coal and shipped to our
customers. As of November 1, 2005, the Enterprise business
unit was operating at a capacity to ship approximately one and
one-half million tons per year.
Nicewonder. The operations we acquired in the Nicewonder
Acquisition constitute a new eighth business unit, although we
may eventually integrate these operations into our seven other
business units. Our Nicewonder business unit produces coal from
three surface mining operations and also recovers coal from the
highway construction business operated by Nicewonder Contracting
Inc. (NCI) described below:
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White Flame Energy operates a surface mine located in Mingo
County, West Virginia, producing low sulfur coal. Coal from this
surface mine is transported by truck to the Mate Creek rail
load-out facility located on the Norfolk Southern Line, where it
is blended with production from NCI and sold to customers.
During 2004, White Flame Energy produced 1.8 million tons
of steam coal. As of November 1, 2005, White Flame Energy
was operating at a capacity to ship approximately
1.8 million tons per year. |
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Premium Energy operates a surface mine in Mingo and Logan
counties, West Virginia, producing high quality steam and
metallurgical coals. The coal produced by Premium Energy is
currently transported to Arch Coal, Inc.s Mingo Logan
mining complex by off road haul. Historically, the vast majority
of Premium Energys production has been sold exclusively to
Mingo Logan. In conjunction with the Nicewonder Acquisition,
Nicewonder agreed to renegotiate the coal sales contract with
Arch Coal, reducing the volume to approximately 1.3 million
tons in 2006 and 0.6 million tons in 2007, and terminating
thereafter. Mingo Logan will continue to process and load the
Premium Energy production for a negotiated price per ton. During
2004, Premium Energy produced 1.7 million tons of
metallurgical grade coal and steam coal. As of November 1,
2005, Premium Energy was operating at a capacity to ship
approximately 1.6 million tons per year. |
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Twin Star, together with Buchanan Energy and Virginia Energy
Company, operate one surface mine in Buchanan County, Virginia,
which during 2004 produced approximately 0.4 million tons
of coal that were sold into the steam and metallurgical markets.
As of November 1, 2005, Twin Star was operating at a
capacity to ship approximately 0.4 million tons per year. |
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Nicewonder Contracting (NCI) operates a highway construction
business under a contract with the State of West Virginia
Department of Transportation. Pursuant to the contract, NCI is
building approximately 11 miles of rough grade highway in
West Virginia over the next six to seven years and, in exchange
NCI will be compensated by West Virginia based on the number of
cubic yards of material excavated and/or filled to create a road
bed, as well as for certain other cost components. In the course
of road construction, NCI will recover any coal encountered and
sell the coal to its customers, subject to certain costs
including coal loading, transportation, coal royalty payments
and applicable taxes and fees. During 2004, NCI produced
approximately 45,000 tons of coal. As of November 1, 2005,
NCI was operating at a capacity to ship approximately
0.5 million tons per year. |
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Coal Characteristics
In general, coal of all geological compositions is characterized
by end use as either steam coal or metallurgical coal. Heat
value, sulfur, ash and moisture content, and coking
characteristics such as fluidity, Audibert-Arnu dilatometer
(ARNU) scores and volatility in the case of metallurgical
coal, are the most important variables in the profitable
marketing and transportation of coal. These characteristics
determine the best end use of a particular type of coal. We
mine, process, market and transport bituminous coal,
characteristics of which are described below.
Heat Value. The heat value of coal is commonly measured
in British thermal units, or Btus. A Btu is the
amount of heat needed to raise the temperature of one pound of
water by one degree Fahrenheit. All of our coal is bituminous
coal, a soft black coal with a heat content that
ranges from 9,500 to 15,000 Btus per pound. This coal is located
primarily in Appalachia, Arizona, the Midwest, Colorado and Utah
and is the type most commonly used for electric power generation
in the United States. Bituminous coal is also used for
metallurgical and industrial steam purposes. Of our estimated
518.9 million tons of proven and probable reserves,
approximately 92% has a heat content above 12,500 Btus per pound.
Sulfur Content. Sulfur content can vary from seam to seam
and sometimes within each seam. When coal is burned, it produces
sulfur dioxide, the amount of which varies depending on the
chemical composition and the concentration of sulfur in the
coal. Low sulfur coals are coals which have a sulfur content of
1.5% or less. Demand for low sulfur coal has increased, and is
expected to continue to increase, as generators of electricity
strive to reduce sulfur dioxide emissions to comply with
increasingly stringent emission standards in environmental laws
and regulations. Approximately 90% of our proven and probable
reserves are low sulfur coal.
High sulfur coal can be burned in plants equipped with
sulfur-reduction technology, such as scrubbers, which can reduce
sulfur dioxide emissions by 50% to 90%. Plants without scrubbers
can burn high sulfur coal by blending it with lower sulfur coal
or by purchasing emission allowances on the open market,
allowing the user to emit a predetermined amount of sulfur
dioxide. Some older coal-fired plants have been retrofitted with
scrubbers, although most have shifted to lower sulfur coals as
their principal strategy for complying with Phase II of the
Clean Air Acts Acid Rain regulations. We expect that any
new coal-fired generation plant built in the United States will
use clean coal-burning technology.
Ash and Moisture Content. 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. The
absence of ash is also important to the process by which
metallurgical coal is transformed into coke for use in steel
production. Moisture content of coal varies by the type of coal
and the region where it is mined. 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 coals weight.
Coking Characteristics. The coking characteristics of
metallurgical coal are typically measured by the coals
fluidity, ARNU and volatility. Fluidity and ARNU tests measure
the expansion and contraction of coal when it is heated under
laboratory conditions to determine the strength of coke that
could be produced from a given coal. Typically, higher numbers
on these tests indicate higher coke strength. Volatility refers
to the loss in mass, less moisture, when coal is heated in the
absence of air. The volatility of metallurgical coal determines
the percentage of feed coal that actually becomes coke, known as
coke yield. Coal with a lower volatility produces a higher coke
yield and is more highly valued than coal with a higher
volatility, all other metallurgical characteristics being equal.
Coal Reserves
We estimate that, as of July 31, 2005, on a pro forma basis
giving effect to the reserves we acquired in the Nicewonder
Acquisition, we had total proven and probable reserves of
approximately 518.9 million
98
tons. We believe that our total proven and probable reserves
will support current production levels for more than
20 years. Reserves are defined by SEC Industry
Guide 7 as that part of a mineral deposit which could be
economically and legally extracted or produced at the time of
the reserve determination. Proven (Measured)
Reserves are defined by SEC Industry Guide 7 as reserves
for which (1) quantity is computed from dimensions revealed
in outcrops, trenches, workings or drill holes; grade and/or
quality are computed from the results of detailed sampling and
(2) 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. Probable reserves are defined by
SEC Industry Guide 7 as reserves for which quantity and grade
and/or quality are computed from information similar to that
used for proven (measured) reserves, but the sites for
inspection, sampling, and measurement are farther apart or are
otherwise less adequately spaced. The degree of assurance,
although lower than that for proven (measured) reserves, is
high enough to assume continuity between points of observation.
Information about our reserves consists of estimates based on
engineering, economic and geological data assembled and analyzed
by our internal engineers, geologists and finance associates. We
periodically update our reserve estimates to reflect past coal
production, new drilling information and other geological or
mining data, and acquisitions or sales of coal properties. Coal
tonnages are categorized according to coal quality, mining
method, permit status, mineability and location relative to
existing mines and infrastructure. In accordance with applicable
industry standards, proven reserves are those for which reliable
data points are spaced no more than 2,700 feet apart.
Probable reserves are those for which reliable data points are
spaced 2,700 feet to 7,900 feet apart. Further
scrutiny is applied using geological criteria and other factors
related to profitable extraction of the coal. These criteria
include seam height, roof and floor conditions, yield and
marketability.
We periodically retain outside experts to independently verify
our estimates of our coal reserves. The most recent of these
reviews, completed in November 2004 (and therefore not including
reserves we acquired in the Nicewonder Acquisition), included
the preparation of reserve maps and the development of estimates
by certified professional geologists based on data supplied by
us and using standards accepted by government and industry,
including the methodology outlined in U.S. Geological
Survey Circular 891. Reserve estimates were developed using
criteria to assure that the basic geologic characteristics of
the reserves (such as minimum coal thickness and wash recovery,
interval between deep mineable seams and mineable area tonnage
for economic extraction) were in reasonable conformity with
existing and recently completed mine operation capabilities on
our various properties. As a result of this report, we increased
our reserve estimate from 326.5 million tons as of
January 1, 2004 to 514.5 million tons as of
October 15, 2004.
In connection with the Nicewonder Acquisition, we asked Marshall
Miller & Associates (MM&A) to prepare a
detailed study of the coal reserves of the Nicewonder Coal Group
in accordance with SEC Industry Guide 7 based on available
geological information. The coal reserve study conducted by
MM&A was planned and performed to obtain reasonable
assurance of the proven and probable coal reserves of the
Nicewonder Coal Group. In connection with the study, MM&A
prepared reserve maps and developed estimates based on data
provided to us by the sellers and using standards accepted by
government and industry. After reviewing such maps and
information, MM&A prepared an independent mapping and
estimate of the proven and probable reserves of the Nicewonder
Coal Group using methodology outlined in SEC Industry
Guide 7. Reserve estimates were developed using criteria to
assure that the basic geologic characteristics of the reserves
(such as minimum coal thickness and wash recovery, interval
between deep mineable seams and mineable area tonnage for
economic extraction) were in reasonable conformity with existing
and recently completed mine operation capabilities on our
various properties.
As with most coal-producing companies in Appalachia, the great
majority of our coal reserves are subject to leases from
third-party landowners. These leases convey mining rights to the
coal producer in exchange for a percentage of gross sales in the
form of a royalty payment to the lessor, subject to minimum
payments. A small portion of our reserve holdings are owned and
require no royalty or per-ton payment to other parties. The
average royalties paid by us for coal reserves from our
producing properties
99
was $3.00 per ton in the first nine months of 2005 and
$2.37 per ton in 2004, representing approximately 4.3% and
4% of our coal sales revenue in the respective periods.
Although our coal leases have varying renewal terms and
conditions, they generally last for the economic life of the
reserves. According to our current mine plans, any leased
reserves assigned to a currently active operation will be mined
during the tenure of the applicable lease. Because the great
majority of our leased or owned properties and mineral rights
are covered by detailed title abstracts prepared when the
respective properties were acquired by predecessors in title to
us and our current lessors, we generally do not thoroughly
verify title to, or maintain title insurance policies on, our
leased or owned properties and mineral rights.
The following table provides the quality (sulfur
content and average Btu content per pound) of our coal reserves,
including, on a pro forma basis, the coal reserves we acquired
in the Nicewonder Acquisition, in each case as of July 31,
2005.
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Recoverable | |
|
|
|
|
|
|
|
|
Reserves Proven & | |
|
Sulfur Content(2) | |
|
Average Btu(2) | |
Regional Business Unit |
|
State | |
|
Probable(1) | |
|
<1% | |
|
1.0%-1.5% | |
|
>1.5% | |
|
>12,500 | |
|
<12,500 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
(In millions of tons) | |
|
(In millions of tons) | |
|
(In millions of tons) | |
Paramont/Alpha Land and Reserves(2)
|
|
|
Virginia |
|
|
|
152.1 |
|
|
|
109.4 |
|
|
|
31.8 |
|
|
|
10.9 |
|
|
|
150.6 |
|
|
|
1.5 |
|
Dickenson-Russell
|
|
|
Virginia |
|
|
|
32.0 |
|
|
|
32.0 |
|
|
|
0 |
|
|
|
0 |
|
|
|
32.0 |
|
|
|
0 |
|
Kingwood
|
|
|
West Virginia |
|
|
|
30.7 |
|
|
|
0 |
|
|
|
18.5 |
|
|
|
12.2 |
|
|
|
30.7 |
|
|
|
0 |
|
Brooks Run
|
|
|
West Virginia |
|
|
|
25.2 |
|
|
|
7.5 |
|
|
|
17.7 |
|
|
|
0 |
|
|
|
10.3 |
|
|
|
15.0 |
|
Welch
|
|
|
West Virginia |
|
|
|
94.7 |
|
|
|
94.7 |
|
|
|
0 |
|
|
|
0 |
|
|
|
94.7 |
|
|
|
0 |
|
AMFIRE
|
|
|
Pennsylvania |
|
|
|
92.0 |
|
|
|
13.8 |
|
|
|
49.3 |
|
|
|
28.8 |
|
|
|
83.1 |
|
|
|
8.9 |
|
Enterprise
|
|
|
Kentucky |
|
|
|
65.5 |
|
|
|
25.5 |
|
|
|
38.4 |
|
|
|
1.6 |
|
|
|
63.4 |
|
|
|
2.1 |
|
Nicewonder
|
|
Virginia and West Virginia |
|
|
26.7 |
|
|
|
26.3 |
|
|
|
0.4 |
|
|
|
0 |
|
|
|
12.0 |
|
|
|
14.7 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Totals
|
|
|
|
|
|
|
518.9 |
|
|
|
309.2 |
|
|
|
156.2 |
|
|
|
53.5 |
|
|
|
476.7 |
|
|
|
42.2 |
|
Percentages
|
|
|
|
|
|
|
|
|
|
|
60 |
% |
|
|
30 |
% |
|
|
10 |
% |
|
|
92 |
% |
|
|
8 |
% |
|
|
(1) |
Recoverable reserves represent the amount of proven and probable
reserves that can actually be recovered taking into account all
mining and preparation losses involved in producing a saleable
product using existing methods under current law. The reserve
numbers set forth in the table exclude reserves for which we
have leased our mining rights to third parties. The reserve
information reflects moisture factors ranging from 4.5% to 6.5%,
representing the average moisture present in our delivered coal. |
|
(2) |
Includes proven and probable reserves in Virginia controlled by
our subsidiary Alpha Land and Reserves, LLC as of July 31,
2005. Alpha Land and Reserves, LLC subleases a portion of the
mining rights to its proven and probable reserves in Virginia to
our subsidiary Paramont Coal Company Virginia, LLC. |
100
The following table summarizes, by regional business unit, the
tonnage of our coal reserves, including, on a pro forma basis,
the coal reserves we acquired in the Nicewonder Acquisition,
that is assigned to our operating mines, our property interest
in those reserves and whether the reserves consist of steam or
metallurgical coal, as of July 31, 2005.
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|
|
|
|
|
|
|
|
|
|
|
Recoverable | |
|
Total Tons(2) | |
|
Total Ton | |
|
|
|
|
|
|
Reserves Proven & | |
|
| |
|
| |
|
|
Regional Business Unit |
|
State | |
|
Probable(1) | |
|
Assigned(2) | |
|
Unassigned(2) | |
|
Owned | |
|
Leased | |
|
Coal Type(3) | |
|
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| |
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| |
|
| |
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| |
|
| |
|
| |
|
| |
|
|
|
|
(In millions of tons) | |
|
|
|
|
|
|
|
|
|
|
|
|
(In millions of tons) | |
|
(In millions of tons) | |
|
|
Paramont/ Alpha Land and Reserves(4)
|
|
|
Virginia |
|
|
|
152.1 |
|
|
|
73.7 |
|
|
|
78.4 |
|
|
|
0 |
|
|
|
152.1 |
|
|
Steam and Metallurgical |
Dickenson-Russell
|
|
|
Virginia |
|
|
|
32.0 |
|
|
|
29.8 |
|
|
|
2.2 |
|
|
|
0 |
|
|
|
32.0 |
|
|
Steam and Metallurgical |
Kingwood
|
|
|
West Virginia |
|
|
|
30.7 |
|
|
|
22.3 |
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|
|
8.4 |
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|
|
0 |
|
|
|
30.7 |
|
|
Steam and Metallurgical |
Brooks Run
|
|
|
West Virginia |
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|
|
25.2 |
|
|
|
2.9 |
|
|
|
22.3 |
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|
|
3.0 |
|
|
|
22.3 |
|
|
Steam and Metallurgical |
Welch
|
|
|
West Virginia |
|
|
|
94.7 |
|
|
|
53.3 |
|
|
|
41.4 |
|
|
|
1.3 |
|
|
|
93.4 |
|
|
Steam and Metallurgical |
AMFIRE
|
|
|
Pennsylvania |
|
|
|
92.0 |
|
|
|
41.9 |
|
|
|
50.1 |
|
|
|
3.5 |
|
|
|
88.5 |
|
|
Steam and Metallurgical |
Enterprise
|
|
|
Kentucky |
|
|
|
65.5 |
|
|
|
10.0 |
|
|
|
55.4 |
|
|
|
7.2 |
|
|
|
58.4 |
|
|
|
Steam |
|
Nicewonder
|
|
|
Virginia and |
|
|
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|
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|
|
Steam and |
|
|
|
|
West Virginia |
|
|
|
26.7 |
|
|
|
24.5 |
|
|
|
2.2 |
|
|
|
1.2 |
|
|
|
25.5 |
|
|
|
Metallurgical |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Totals
|
|
|
|
|
|
|
518.9 |
|
|
|
258.4 |
|
|
|
260.5 |
|
|
|
16.1 |
|
|
|
502.8 |
|
|
|
|
|
Percentages
|
|
|
|
|
|
|
|
|
|
|
50 |
% |
|
|
50 |
% |
|
|
3 |
% |
|
|
97 |
% |
|
|
|
|
|
|
(1) |
Recoverable reserves represent the amount of proven and probable
reserves that can actually be recovered taking into account all
mining and preparation losses involved in producing a saleable
product using existing methods under current law. The reserve
numbers set forth in the table exclude reserves for which we
have leased our mining rights to third parties. The reserve
information reflects moisture factors ranging from 4.5% to 6.5%,
representing the average moisture present in our delivered coal. |
|
(2) |
Assigned reserves represent recoverable coal reserves that can
be mined without a significant capital expenditure for mine
development, whereas unassigned reserves will require
significant capital expenditures to mine the reserves. |
|
(3) |
Almost all of our reserves that we currently market as
metallurgical coal also possess quality characteristics that
would enable us to market them as steam coal. |
|
(4) |
Includes proven and probable reserves in Virginia controlled by
our subsidiary Alpha Land and Reserves, LLC as of July 31,
2005. Alpha Land and Reserves, LLC subleases a portion of the
mining rights to its proven and probable reserves in Virginia to
our subsidiary Paramont Coal Company Virginia, LLC. |
Marketing, Sales and Customer Contracts
Our marketing and sales force, which is principally based in
Latrobe, Pennsylvania, included 34 employees as of
November 1, 2005, and consists of sales managers,
distribution/traffic managers and administrative personnel. In
addition to selling coal produced in our seven regional business
units, we are also actively involved in the purchase and resale
of coal mined by others, the majority of which we blend with
coal produced from our mines. We have coal supply commitments
with a wide range of electric utilities, steel manufacturers,
industrial customers and energy traders and brokers. Our overall
sales philosophy is to focus first on the customers
individual needs and specifications, as opposed to simply
selling our production inventory. By offering coal of both steam
and metallurgical grades blended to provide specific qualities
of heat content, sulfur and ash and other characteristics
relevant to our customers, we are able to serve a diverse
customer base. This diversity allows us to adjust to changing
101
market conditions and provides us with the ability to sustain
high sales volumes and sales prices for our coal. Many of our
larger customers are well-established public utilities who have
been customers of ours or our Predecessor and acquired companies
for decades.
We sold a total of 18.9 million tons of coal in the first
nine months of 2005, consisting of 14.9 million tons of
produced and processed coal and 4.0 million tons of
purchased coal that we resold without processing. Of our total
purchased coal sales of 5.0 million tons in the first nine
months of 2005, approximately 3.5 million tons were blended
prior to resale, meaning the coal was mixed with coal produced
from our mines prior to resale, which generally allows us to
realize a higher overall margin for the blended product than we
would be able to achieve selling these coals separately.
Approximately 1.0 million tons of our purchased coal sales
during the first nine months of 2005 were processed by us,
meaning we washed, crushed or blended the coal at one of our
preparation plants or loading facilities prior to resale. We
sold a total of 25.3 million tons of coal in 2004,
consisting of 18.9 million tons of produced and processed
coal and 6.4 million tons of purchased coal that we resold
without processing. Of our total purchased coal sales of
7.3 million tons in 2004, approximately 5.9 million
tons were blended prior to resale. Approximately
0.9 million tons of our 2004 purchased coal sales were
processed by us. We sold a total of 21.6 million tons of
coal in 2003, consisting of 17.7 million tons of produced
and processed coal and 3.9 million tons of purchased coal
that we resold without processing. Of our total purchased coal
sales of 5.4 million tons in 2003, approximately
1.5 million tons were processed prior to resale. The
breakdown of tons sold by market served for the first six months
of 2005 and for 2004 and 2003 is set forth in the table below:
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|
|
|
|
|
|
|
Steam Coal Sales(1) | |
|
Metallurgical Coal Sales | |
|
|
| |
|
| |
Year |
|
Tons | |
|
% of Total Sales | |
|
Tons | |
|
% of Total Sales | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In millions, except percentages) | |
Nine Months Ended September 30, 2005
|
|
|
11.7 |
|
|
|
62 |
% |
|
|
7.2 |
|
|
|
38 |
% |
2004
|
|
|
15.8 |
|
|
|
63 |
% |
|
|
9.5 |
|
|
|
37 |
% |
2003
|
|
|
15.3 |
|
|
|
71 |
% |
|
|
6.3 |
|
|
|
29 |
% |
|
|
(1) |
Steam coal sales include sales to utility and industrial
customers. Sales of steam coal to industrial customers, who we
define as consumers of steam coal who do not generate
electricity for sale to third parties, accounted for
approximately 7%, 4% and 5% of total sales in the first nine
months of 2005 and 2004 and 2003, respectively. |
We sold coal to over 130 different customers in 2004. Our top
ten customers in 2004 accounted for approximately 39% of 2004
revenues and our largest customer during 2004 accounted for
approximately 8% of 2004 revenues. The following table provides
information regarding our exports (including to Canada and
Mexico) in 2004 and 2003 by revenues and tons sold:
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Export Tons | |
|
|
|
Export Sales | |
|
|
|
|
Sold as a | |
|
|
|
Revenues as a | |
|
|
Export Tons | |
|
Percentage of | |
|
Export Sales | |
|
Percentage of | |
Year |
|
Sold | |
|
Total Coal Sales | |
|
Revenues(1) | |
|
Total Revenues | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(In millions, except percentages) | |
2004
|
|
|
8.3 |
|
|
|
32 |
% |
|
$ |
602.6 |
|
|
|
47 |
% |
2003
|
|
|
4.9 |
|
|
|
22 |
% |
|
$ |
220.8 |
|
|
|
28 |
% |
|
|
(1) |
Export sales revenues in 2004 include approximately
$4.0 million in equipment export sales. All other export
sales revenues are coal sales revenues and freight and handling
revenues. |
Our export shipments during 2004 and 2003 serviced customers in
18 and 11 countries, respectively, across North America,
Europe, South America, Asia and Africa. Japan was our largest
export market in 2004 with sales to Japan accounting for
approximately 23% of export revenues and approximately 11% of
total revenues in 2004, while Canada was our largest export
market in 2003, with sales to Canada accounting for
approximately 40% of export revenues and approximately 11% of
total revenues in 2003. All of our sales are made in
U.S. dollars, which reduces foreign currency risk. A
portion of our sales are subject to seasonal fluctuation, with
sales to certain customers being curtailed during the winter
months due to the freezing of lakes that we use to transport
coal to those customers.
102
As is customary in the coal industry, when market conditions are
appropriate and particularly in the steam coal market, we enter
into long-term contracts (exceeding one year in duration) with
many of our customers. These arrangements allow customers to
secure a supply for their future needs and provide us with
greater predictability of sales volume and sales prices. A
significant majority of our steam coal sales are shipped under
long-term contracts. During 2003, most of our contracts to
supply metallurgical coal were entered into on a one-year
rolling basis or on a current market or spot basis. However, due
to market conditions, the majority of the metallurgical coal
sales contracts we entered into during 2004 were long-term
contracts. Approximately 83% and 55% of our steam and
metallurgical coal sales volume in 2004, respectively, was
delivered pursuant to long-term contracts.
As of December 31, 2005, we had contracts to sell
approximately 88% of planned 2006 production, 46% of planned
2007 production, and 23% of planned 2008 production. In
addition, as of December 31, 2005, we had commitments to
purchase 3.7 million and 0.5 million tons of coal
during 2006 and 2007, respectively.
The terms of our contracts result from bidding and negotiations
with customers. Consequently, the terms of these contracts
typically vary significantly in many respects, including price
adjustment features, provisions permitting renegotiation or
modification of coal sale prices, coal quality requirements,
quantity parameters, flexibility and adjustment mechanisms,
permitted sources of supply, treatment of environmental
constraints, options to extend and force majeure, suspension,
termination and assignment provisions, and provisions regarding
the allocation between the parties of the cost of complying with
future governmental regulations.
Distribution
We employ transportation specialists who negotiate freight and
terminal agreements with various providers, including railroads,
trucks, barge lines, and terminal facilities. Transportation
specialists also coordinate with customers, mining facilities
and transportation providers to establish shipping schedules
that meet the customers needs. Our coal sales of
25.3 million tons during 2004 were loaded from our 11
preparation plants and in certain cases directly from our mines
and, in the case of purchased coal, in some cases directly from
mines and preparation plants operated by third parties or from
an export terminal. Virtually all of our coal is transported
from the mine to our preparation plants by truck or rail, and
then from the preparation plant to the customer by means of
railroads, trucks, barge lines and ocean-going vessels from
terminal facilities. Rail shipments constituted approximately
79% of total shipments of captive produced and processed coal
volume from the preparation plant to the customer in 2004. The
balance was shipped from our preparation plants, loadout
facilities or mines via truck. In 2004, approximately 11% of our
coal sales were ultimately delivered to customers through
transport on the Great Lakes, approximately 14% was moved
through the Norfolk Southern export facility at Norfolk,
Virginia, approximately 6% was moved through the coal export
terminal at Newport News, Virginia operated by Dominion Terminal
Associates, and 5% was moved through the export terminal at
Baltimore, Maryland. We own a 32.5% interest in the coal export
terminal at Newport News, Virginia operated by Dominion Terminal
Associates. See Other Operations. Of the
3.7 million tons of coal sold by the Nicewonder Coal Group
in 2004, 55% was shipped via the Norfolk Southern Rail, and the
remaining 45% was delivered via truck to other coal companies
for resale.
Competition
With respect to our U.S. customers, we compete with
numerous coal producers in the Appalachian region and with a
large number of western coal producers in the markets that we
serve. Competition from coal with lower production costs shipped
east from western coal mines has resulted in increased
competition for coal sales in the Appalachian region. We face
limited competition from imports for our domestic customers. In
2004, only 2.5% of total U.S. coal consumption was
imported. Excess industry capacity, which has occurred in the
past, tends to result in reduced prices for our coal. The most
important factors on which we compete are delivered coal price,
coal quality and characteristics, transportation costs from the
mine to the customer and the reliability of supply. Demand for
coal and the prices that we will
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be able to obtain for our coal are closely linked to coal
consumption patterns of the domestic electric generation
industry, which has accounted for approximately 91% of domestic
coal consumption over the last five years. These coal
consumption patterns are influenced by factors beyond our
control, including the demand for electricity, which is
significantly dependent upon summer and winter temperatures in
the United States, environmental and other government
regulations, technological developments and the location,
availability, quality and price of competing fuels for power
such as natural gas, nuclear, fuel oil and alternative energy
sources such as hydroelectric power. Demand for our low sulfur
coal and the prices that we will be able to obtain for it will
also be affected by the price and availability of high sulfur
coal, which can be marketed in tandem with emissions allowances
in order to meet Clean Air Act requirements.
Demand for our metallurgical coal and the prices that we will be
able to obtain for metallurgical coal will depend to a large
extent on the demand for U.S. and international steel, which is
influenced by factors beyond our control, including overall
economic activity and the availability and relative cost of
substitute materials. In the export metallurgical market, during
2004 we largely competed with producers from Australia, Canada,
and other international producers of metallurgical coal.
In addition to competition for coal sales in the United States
and internationally, we compete with other coal producers,
particularly in the Appalachian region, for the services of
experienced coal industry employees at all levels of our mining
operations.
Other Operations
We have other operations and activities in addition to our
normal coal production, processing and sales business, including:
Maxxim Rebuild Company. We own Maxxim Rebuild Company,
LLC, a mining equipment company with facilities in Kentucky and
Virginia. This business largely consists of repairing and
reselling equipment and parts used in surface mining and in
supporting preparation plant operations. Maxxim Rebuild had
revenues of $20.8 million for 2004, of which approximately
22% was generated by services provided to our other subsidiaries
and approximately 19% was generated by equipment sales to export
customers.
Dominion Terminal Associates. Through our subsidiary
Alpha Terminal Company, LLC, we hold a 32.5% interest in
Dominion Terminal Associates, a 22 million-ton annual
capacity coal export terminal located in Newport News, Virginia.
The terminal, constructed in 1982, provides the advantages of
state of the art unloading/transloading equipment with ground
storage capability, providing producers with the ability to
custom blend export products without disrupting mining
operations. During 2004, we shipped a total of 1.4 million
tons of coal to our customers through the terminal. We make
periodic cash payments in respect of the terminal for operating
expenses, which are offset by payments we receive for
transportation incentive payments and for renting our unused
storage space in the terminal to third parties. Our cash
payments for expenses for the terminal in 2004 were
$3.3 million, partially offset by payments received in 2004
of $1.8 million. The terminal is held in a partnership with
subsidiaries of three other companies, Dominion Energy (20%),
Arch Coal (17.5%) and Peabody Energy (30%). Alpha Terminal
Company and its other interested partners are currently pursuing
an investment of approximately $35.0 million in the
construction of a new coal import facility at the terminal.
Engineering and permitting work on the project has been
completed, and construction is expected to begin in the second
half of 2006. The parties are currently in the process of
determining which partners will participate in the investment.
Miscellaneous. We engage in the sale of certain
non-strategic assets such as timber, gas and oil rights as well
as the leasing and sale of non-strategic surface properties and
reserves. We also provide coal and environmental analysis
services.
Employee and Labor Relations
Approximately 95% of our coal production in 2004 came from mines
operated by union-free employees, and as of November 1,
2005, over 91% of our subsidiaries approximately 3,240
employees were
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union-free. We believe our employee relations are good and there
have been no material work stoppages at any of our
subsidiaries properties in the past ten years.
Legal Proceedings
General. From time to time, we are involved in litigation
and administrative proceedings which arise in the ordinary
course of our business. Management does not believe that any of
the litigation or proceedings in which we are currently
involved, either individually or in the aggregate, are likely to
have a material adverse effect on our business, financial
condition, operating results or cash flows.
Nicewonder Litigation. The Affiliated Construction Trades
Foundation brought an action against Nicewonder Contracting,
Inc. (NCI) and the West Virginia Department of
Transportation, Division of Highways in the United States
District Court in the Southern District of West Virginia.
(The Affiliated Construction Trades Foundation v. West
Virginia Department of Transportation and Nicewonder Contracting
Inc., (SDWV CA No. 2:04-1344)). The plaintiff seeks a
declaration that the contract between NCI and the State of West
Virginia related to NCIs road construction project is
illegal as a violation of applicable West Virginia and federal
competitive bidding and prevailing wage laws. The plaintiff also
is seeking an injunction prohibiting performance of the contract
but has not sought monetary damages. The sellers in the
Nicewonder Acquisition have agreed to indemnify us for any
losses we may incur as a result of this litigation, net of the
net revenues of NCI from post-acquisition coal sales and the
value of certain reserves, surface property and mining equipment
of NCI.
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ENVIRONMENTAL AND OTHER 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. These
regulations and legislation have had, and will continue to have,
a significant effect on our production costs and our competitive
position. Future legislation, regulations or orders, as well as
future interpretations and more rigorous enforcement of existing
laws, regulations or orders, may require substantial increases
in equipment and operating costs to us and delays,
interruptions, or a termination of operations, the extent of
which we cannot predict. We intend to respond to these
regulatory requirements at the appropriate time by implementing
necessary modifications to facilities or operating procedures.
Future legislation, regulations or orders may also cause coal to
become a less attractive fuel source, thereby reducing
coals share of the market for fuels used to generate
electricity. As a result, future legislation, regulations or
orders may adversely affect our mining operations, cost
structure or the ability of our customers to use coal.
We endeavor to conduct our mining operations in compliance with
all applicable federal, state, and local laws and regulations.
However, because of extensive and comprehensive regulatory
requirements, violations occur from time to time. None of the
violations or the monetary penalties assessed upon us since our
inception in 2002 have been material. Nonetheless, we expect
that future liability under or compliance with environmental and
safety requirements could have a material effect on our
operations or competitive position. Under some circumstances,
substantial fines and penalties, including revocation or
suspension of mining permits, may be imposed under the laws
described below. Monetary sanctions and, in severe
circumstances, criminal sanctions may be imposed for failure to
comply with these laws.
As of September 30, 2005, we had accrued $41.0 million
for reclamation liabilities and mine closures, including
$6.7 million of current liabilities.
Mining Permits and Approvals. Numerous governmental
permits or approvals are required for mining operations. When we
apply for these permits and approvals, we may be required to
present data to federal, state or local authorities pertaining
to the effect or impact that any proposed production or
processing of coal may have upon the environment. The
requirements imposed by any of these authorities may be costly
and time consuming and may delay commencement or continuation of
mining operations. Regulations also provide that a mining permit
or modification can be delayed, refused or revoked if an
officer, director or a stockholder with a 10% or greater
interest in the entity is affiliated with or is in a position to
control another entity that has outstanding permit violations.
Thus, past or ongoing violations of federal and state mining
laws could provide a basis to revoke existing permits and to
deny the issuance of additional permits.
In order to obtain mining permits and approvals from state
regulatory authorities, mine operators, including us, must
submit a reclamation plan for restoring, upon the completion of
mining operations, the mined property to its prior or better
condition, productive use or other permitted condition.
Typically, we submit our necessary permit applications several
months, or even years, before we plan to begin mining a new
area. Although permits may take six months or longer to obtain,
in the past we have generally obtained our mining permits
without significant delay. However, we cannot be sure that we
will not experience difficulty in obtaining mining permits in
the future.
Surface Mining Control and Reclamation Act. The Surface
Mining Control and Reclamation Act of 1977 (SMCRA),
which is administered by the 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 from the OSM or the applicable state agency. Where
state regulatory agencies have adopted federal mining programs
under SMCRA, the state becomes the regulatory authority. States
in which we have active mining operations have achieved primary
control of enforcement through federal authorization.
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SMCRA permit provisions include a complex set of requirements
which include: 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 and historical resources, soils, vegetation,
wildlife, assessment of surface and ground water hydrology,
climatology, and wetlands. In conducting this work, we collect
geologic data to define and model the soil and rock structures
and coal that we will mine. We develop mining and reclamation
plans by utilizing this geologic data and incorporating elements
of the environmental data. The mining and reclamation plan
incorporates the provisions of SMCRA, the state programs, and
the complementary environmental programs that affect 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 OSMs Applicant Violator System,
including the mining and compliance history of officers,
directors and principal owners of the entity.
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
that also provides 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 may take
six months to two years or even longer to be issued. Regulatory
authorities have considerable discretion in the timing of the
permit issuance and the public and other agencies have 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 or abandoned prior to
SMCRAs adoption in 1977. The current fee is $0.35 per
ton on surface-mined coal and $0.15 per ton on deep-mined
coal, but tax rate revisions are currently pending. On
April 4, 2005, the United States Court of Federal Claims
ruled that this fee is unconstitutional to the extent it is
levied on exported coal. We do not know whether the
U.S. government will appeal this ruling.
SMCRA stipulates compliance with many other major environmental
statutes, including: the Clean Air Act; Clean Water Act;
Resource Conservation and Recovery Act (RCRA) and
Comprehensive Environmental Response, Compensation and Liability
Act (CERCLA or Superfund).
Surety Bonds. Federal and state laws require us to obtain
surety bonds to secure payment of certain long-term obligations
including mine closure or reclamation costs, federal and state
workers compensation costs, coal leases and other
miscellaneous obligations. Many of these bonds are renewable on
a yearly basis. Surety bond costs have increased in recent years
while the market terms of surety bonds have generally become
more unfavorable. In addition, the number of companies willing
to issue surety bonds has decreased. We have a committed bonding
facility with Travelers Casualty and Surety Company of America,
pursuant to which Travelers has agreed, subject to certain
conditions, to issue surety bonds on our behalf in a maximum
amount of $150.0 million. As of September 30, 2005, we
have posted an aggregate of $88.9 million in reclamation
bonds and $8.6 million of other types of bonds under this
facility. On a pro forma basis giving effect to the Nicewonder
Acquisition, we would have posted an aggregate of
$100.7 million in reclamation bonds under this facility as
of September 30, 2005.
Clean Air Act. The Clean Air Act and comparable state
laws that regulate air emissions 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 2.5 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
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emitted by coal-fired electricity generating plants. The general
effect of this extensive regulation of emissions from coal-fired
power plants could be to reduce demand for coal.
Clean Air Act requirements that may directly or indirectly
affect our operations include the following:
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Acid Rain. Title IV of the Clean Air Act required a
two-phase reduction of sulfur dioxide emissions by electric
utilities. Phase II became effective in 2000 and applies to
all coal-fired power plants generating greater than
25 Megawatts. The affected electricity generators have
sought to meet these requirements by, among other compliance
methods, switching to lower sulfur fuels, installing pollution
control devices, reducing electricity generating levels or
purchasing sulfur dioxide emission allowances. We cannot
accurately predict the effect of these provisions of the Clean
Air Act on us in future years. At this time, we believe that
implementation of Phase II has resulted in an upward
pressure on the price of lower sulfur coals, as coal-fired power
plants continue to comply with the more stringent restrictions
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Fine Particulate Matter. The Clean Air Act requires the
U.S. Environmental Protection Agency (the EPA)
to set standards, referred to as National Ambient Air Quality
Standards (NAAQS), for certain pollutants. Areas
that are not in compliance (referred to as non-attainment
areas) with these standards must take steps to reduce
emissions levels. There currently are NAAQS for particulate
matter with an aerodynamic diameter less than or equal to 10
microns, or PM10, and for fine particulate matter with an
aerodynamic diameter less than or equal 2.5 microns, or PM2.5.
The EPA designated all or part of 225 counties in 20 states as
well as the District of Columbia as non-attainment areas with
respect to the PM2.5 NAAQS. Individual states must identify the
sources of emissions and develop emission reduction plans. These
plans may be state-specific or regional in scope. Under the
Clean Air Act, individual states have up to twelve years from
the date of designation to secure emissions reductions from
sources contributing to the problem. Meeting the new PM2.5
standard may require reductions of nitrogen oxide and sulfur
dioxide emissions. Future regulation and enforcement of the new
PM2.5 standard will affect many power plants, especially
coal-fired plants and all plants in non-attainment
areas. |
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Ozone. Significant additional emissions control
expenditures will be required at coal-fired power plants to meet
the current NAAQS for ozone. Nitrogen oxides, which are a
by-product of coal combustion, can lead to the creation of
ozone. Accordingly, emissions control requirements for new and
expanded coal-fired power plants and industrial boilers will
continue to become more demanding in the years ahead. For
example, the EPA is in the process of replacing the existing
standards with more stringent ones. The EPA designated counties
in 32 states as non-attainment areas under the new standard.
These states will have until June 2007 to develop plans for
pollution control measures that allow them to comply with the
standards. |
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NOx SIP Call. The NOx SIP Call program was established by
the EPA in October of 1998 to reduce the transport of ozone on
prevailing winds from the Midwest and South to states in the
Northeast, which said they could not meet federal air quality
standards because of migrating pollution. The program is
designed to reduce nitrous oxide emissions by one million tons
per year in 22 eastern states and the District of Columbia.
Installation of additional control measures, such as selective
catalytic reduction devices, required under the final rules will
make it more costly to operate coal-fired electricity generating
plants, thereby making coal a less attractive fuel. |
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Clear Skies Initiative. The Bush Administration has
proposed legislation, commonly referred to as the Clear Skies
Initiative, that could require dramatic reductions in nitrous
oxide, sulfur dioxide, and mercury emissions by power plants
through cap-and-trade programs similar to the
existing Acid Rain regulations and current NOx budget programs.
It is currently not possible to predict what, if any, new
regulatory requirements will ultimately evolve out of this
initiative. |
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Clean Air Interstate Rule. The EPA finalized the Clean
Air Interstate Rule (CAIR) on March 10, 2005. The new
CAIR calls for power plants in 29 eastern states and the
District of Columbia to reduce emission levels of sulfur dioxide
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regulate power plants under a cap and trade program similar to
the system now in effect for acid deposition control and to that
proposed by the Clear Skies Initiative. When fully implemented,
this rule is expected to reduce regional sulfur dioxide
emissions by over 70% and nitrogen oxides emissions by over 60%
from 2003 levels. The stringency of the cap may require many
coal-fired electricity generation plants to install additional
pollution control equipment, such as wet scrubbers, to comply,
which could decrease the demand for low sulfur coal at these
plants and thereby potentially reduce market prices for low
sulfur coal. Emissions are permanently capped and cannot
increase. On December 3, 2005, the EPA published a notice
that it was reconsidering four specific issues that are involved
in this rule and was accepting public comment until
January 13, 2006. The rule is also subject to judicial
challenge, which makes its impact difficult to assess. |
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Clean Air Mercury Rule. On March 15, 2005, the EPA
issued the Clean Air Mercury Rule to permanently cap and reduce
mercury emissions from coal-fired power plants. The Clean Air
Mercury Rule establishes mercury emissions limits from new and
existing coal-fired power plants and creates a market-based
cap-and-trade program that is expected to reduce nationwide
utility emissions of mercury in two phases. Several states and
environmental groups have filed suits in the U.S. Court of
Appeals for the District of Columbia challenging the EPAs
decision to allow emissions trading and its decision to reverse
a regulatory finding in 2000 that would have required emission
limits for mercury based maximum achievable control technology
under section 112 of the Clean Air Act. Many of the
challenges seek to impose more stringent rules. In addition,
efforts have commenced in Congress to legislatively disapprove
the rules. The EPA recently announced that it is seeking further
public comment on the Clean Air Mercury Rule and is
reconsidering the decision not to regulate mercury and other
pollutants from coal-fired power plants under the Clean Air
Acts hazardous air pollution program. Stricter limitations
on mercury emissions from power plants may adversely affect the
demand for coal. |
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Carbon Dioxide. In February 2003, a number of states
notified the EPA that they planned 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, three of these states sued the EPA seeking a court order
requiring the EPA to designate carbon dioxide as a criteria
pollutant and to issue a new NAAQS for carbon dioxide. If these
lawsuits result in the issuance of a court order requiring the
EPA to set emission limitations for carbon dioxide and/or lower
emission limitations for sulfur dioxide and particulate matter,
it could reduce the amount of coal our customers would purchase
from us. |
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Regional Emissions Trading. Eleven Northeast and
Mid-Atlantic states are working cooperatively to develop a
regional cap and trade program that would initially cover carbon
dioxide emissions from power plants in the region. No formal
model rule has been made public to date. There are a number of
uncertainties regarding this initiative, including the
applicable baseline of emissions to be permitted, initial
allocations, required emissions reductions, availability of
offsets, the extent to which states will adopt the program,
whether it will be linked with programs in other states or in
Canadian provinces, and the timing for implementation of the
program. There can be no assurance at this time that a carbon
dioxide cap and trade program, if implemented by the states
where our customers operate, will not affect the future market
for coal in this region. |
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Regional Haze. The EPA has initiated a regional haze
program designed to protect and to improve visibility at and
around national parks, national wilderness areas and
international parks. This program restricts the construction of
new coal-fired power plants whose operation may impair
visibility at and around federally protected areas. Moreover,
this program may require certain existing coal-fired power
plants to install additional control measures designed to limit
haze-causing emissions, such as sulfur dioxide, nitrogen oxides,
volatile organic chemicals and particulate matter. These
limitations could affect the future market for coal. |
Clean Water Act. The Clean Water Act of 1972 (the
CWA) and corresponding state laws affect coal mining
operations by imposing restrictions on the discharge of certain
pollutants into water and on
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dredging and filling wetlands. The CWA establishes in-stream
water quality standards and treatment standards for wastewater
discharge through the National Pollutant Discharge Elimination
System (NPDES). Regular monitoring, as well as
compliance with reporting requirements and performance
standards, are preconditions for the issuance and renewal of
NPDES permits that govern the discharge of pollutants into water.
Permits under Section 404 of the CWA are required for coal
companies to conduct dredging or filling activities in
jurisdictional waters for the purpose of creating slurry ponds,
water impoundments, refuse areas, valley fills or other mining
activities. Jurisdictional waters typically include ephemeral,
intermittent, and perennial streams and may in certain instances
include man-made conveyances that have a hydrologic connection
to a stream or wetland.
The Army Corps of Engineers (the COE) is empowered
to issue nationwide permits for specific categories
of filling activity that are determined to have minimal
environmental adverse effects in order to save the cost and time
of issuing individual permits under Section 404. Nationwide
Permit 21 authorizes the disposal of dredge-and-fill material
from mining activities into the waters of the United States. On
October 23, 2003, several citizens groups sued the COE in
the U.S. District Court for the Southern District of West
Virginia seeking to invalidate nationwide permits
utilized by the COE and the coal industry for permitting most
in-stream disturbances associated with coal mining, including
excess spoil valley fills and refuse impoundments. Although the
lower court enjoined the issuance of Nationwide 21 permits,
that decision was overturned by the Fourth Circuit Court of
Appeals, which concluded that the COE complied with the CWA in
promulgating this permit. Although Alpha had no operations that
were interrupted, the lower courts decision required us to
convert certain ongoing and planned applications for Nationwide
21 permits to applications for individual permits. A similar
lawsuit was filed on January 27, 2005 in the
U.S. District Court for the Eastern District of Kentucky,
and other lawsuits may be filed in other states where Alpha
operates.
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.
Some of our operations currently discharge effluents into stream
segments that have been designated as impaired. The adoption of
new TMDL related effluent limitations for our coal mines could
require more costly water treatment and could adversely affect
our coal production.
Under the CWA, states must conduct an anti-degradation review
before approving permits for the discharge of pollutants to
waters that have been designated as high quality. A states
anti-degradation regulations would prohibit the diminution of
water quality in these streams. Several environmental groups and
individuals recently challenged, and in part successfully, West
Virginias anti-degradation policy. In general, waters
discharged from coal mines to high quality streams will be
required to meet or exceed new high quality
standards. This could cause increases in the costs, time and
difficulty associated with obtaining and complying with NPDES
permits, and could aversely affect our coal production.
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. All of the states
in which we operate 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 this regulation has a significant
effect on our operating costs, our U.S. competitors are
subject to the same degree of regulation.
Under the Black Lung Benefits Revenue Act of 1977 and the Black
Lung Benefits Reform Act of 1977, as amended in 1981, each coal
mine operator must secure payment of federal black lung benefits
to claimants who are current and former employees and to a trust
fund for the payment of benefits and medical expenses to
claimants who last worked in the coal industry prior to
July 1, 1973. The trust fund is
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funded by an excise tax on production of up to $1.10 per
ton for deep-mined coal and up to $0.55 per ton for
surface-mined coal, neither amount to exceed 4.4% of the gross
sales price. The excise tax does not apply to coal shipped
outside the United States. In 2004, we recorded
$12.6 million of expense related to this excise tax.
Coal Industry Retiree Health Benefit Act of 1992. Unlike
many companies in the coal business, we do not have any
liability under the Coal Industry Retiree Health Benefit Act of
1992 (the Coal Act), which requires the payment of
substantial sums to provide lifetime health benefits to
union-represented miners (and their dependents) who retired
before 1992, because liabilities under the Coal Act that had
been imposed on our Predecessor or acquired companies were
retained by the sellers and, if applicable, their parent
companies, in the applicable acquisition agreements. We should
not be liable for these liabilities retained by the sellers
unless they and, if applicable, their parent companies, fail to
satisfy their obligations with respect to Coal Act claims and
retained liabilities covered by the acquisition agreements.
Endangered Species Act. The federal Endangered Species
Act and counterpart state legislation protect species threatened
with possible extinction. Protection of threatened and
endangered species may have the effect of prohibiting or
delaying us from obtaining mining permits and may include
restrictions on timber harvesting, road building and other
mining or agricultural activities in areas containing the
affected species or their habitats. A number of species
indigenous to the areas in which we operate are protected under
the Endangered Species Act. Based on the species that have been
identified to date and the current application of applicable
laws and regulations, however, we do not believe there are any
species protected under the Endangered Species Act that would
materially and adversely affect our ability to mine coal from
our properties in accordance with current mining plans.
Resource Conservation and Recovery Act. The RCRA affects
coal mining operations by establishing requirements for the
treatment, storage, and disposal of hazardous wastes. Certain
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, such as coal ash. 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.
Most state hazardous waste laws also exempt coal combustion
waste, and instead treat it as either a solid waste or a special
waste. Any costs associated with handling or disposal of
hazardous wastes would increase our customers operating
costs and potentially reduce their ability to purchase coal. In
addition, contamination caused by the past disposal of ash can
lead to material liability.
Due to the hazardous waste exemption for coal combustion waste
such as ash, much coal combustion waste is currently put to
beneficial use. For example, in one Pennsylvania mine from which
we have the right to receive coal, we have used some ash as mine
fill. The ash we use for this purpose is mixed with lime and
serves to help alleviate the potential for acid mine drainage.
Federal and State Superfund Statutes. Superfund and
similar state laws affect coal mining and hard rock operations
by creating 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. In addition, mining operations may have reporting
obligations under the Emergency Planning and Community Right to
Know Act and the Superfund Amendments and Reauthorization Act.
111
Climate Change. One major by-product of burning coal is
carbon dioxide, which is considered a greenhouse gas and is a
major source of concern with respect to global warming. In
November 2004, Russia ratified the Kyoto Protocol to the 1992
Framework Convention on Global Climate Change (the
Protocol), which establishes a binding set of
emission targets for greenhouse gases. With Russias
accedence, the Protocol now has sufficient support and became
binding on all those countries that have ratified it on
February 16, 2005. Four industrialized nations have refused
to ratify the Protocol Australia, Liechtenstein,
Monaco, and the United States. Although the targets vary from
country to country, if the United States were to ratify the
Protocol our nation would be required to reduce greenhouse gas
emissions to 93% of 1990 levels from 2008 to 2012. Canada, which
accounted for 6% of our sales volume in 2004, ratified the
Protocol in 2002. Under the Protocol, Canada will be required to
cut greenhouse gas emissions to 6% below 1990 levels in 2008 to
2012, either in direct reductions in emissions or by obtaining
credits through the Protocols market mechanisms. This
could result in reduced demand for coal by Canadian electric
power generators.
Future regulation of greenhouse gases in the United States could
occur pursuant to future U.S. treaty obligations, statutory
or regulatory changes under the Clean Air Act, or otherwise. The
Bush Administration has proposed a package of voluntary emission
reductions for greenhouse gases reduction targets which provide
for certain incentives if targets are met. Some states, such as
Massachusetts, have already issued regulations regulating
greenhouse gas emissions from large power plants. Further, in
2002, the Conference of New England Governors and Eastern
Canadian Premiers adopted a Climate Change Action Plan, calling
for reduction in regional greenhouse emissions to 1990 levels by
2010, and a further reduction of at least 10% below 1990 levels
by 2020. Increased efforts to control greenhouse gas emissions,
including the future ratification of the Protocol by the U.S.,
could result in reduced demand for coal.
112
MANAGEMENT
Directors and Executive Officers
The following table sets forth the names, ages and titles of our
directors and executive officers.
|
|
|
|
|
|
|
Name |
|
Age | |
|
Position |
|
|
| |
|
|
Michael J. Quillen
|
|
|
57 |
|
|
President, Chief Executive Officer and Director |
Kevin S. Crutchfield
|
|
|
44 |
|
|
Executive Vice President |
D. Scott Kroh
|
|
|
55 |
|
|
Executive Vice President |
David C. Stuebe
|
|
|
65 |
|
|
Vice President and Chief Financial Officer |
Michael D. Brown
|
|
|
44 |
|
|
Vice President |
Vaughn R. Groves
|
|
|
49 |
|
|
Vice President and General Counsel |
Eddie W. Neely
|
|
|
54 |
|
|
Vice President and Controller |
E. Linn Draper, Jr.
|
|
|
63 |
|
|
Director |
Glenn A. Eisenberg
|
|
|
44 |
|
|
Director |
John W. Fox, Jr.
|
|
|
58 |
|
|
Director |
Alex T. Krueger
|
|
|
31 |
|
|
Director |
Fritz R. Kundrun
|
|
|
69 |
|
|
Director |
William E. Macaulay
|
|
|
60 |
|
|
Director |
Hans J. Mende
|
|
|
61 |
|
|
Director and Chairman of the Board |
Each officer serves at the discretion of our board of directors
and holds office until his or her successor is elected and
qualified or until his or her earlier resignation or removal.
There are no family relationships among any of our directors or
executive officers.
Set forth below is a description of the background of the
persons named above.
Michael J. Quillen has served as our President and Chief
Executive Officer and a member of our board of directors since
our formation in November 2004. Mr. Quillen joined the
Alpha management team as President and the sole manager of Alpha
Natural Resources, LLC, our top-tier operating subsidiary, in
August 2002, and has served as Chief Executive Officer of Alpha
Natural Resources, LLC since January 2003. He has also served as
the President and a member of the board of directors of ANR
Holdings since December 2002, and as the Chief Executive Officer
of ANR Holdings since March 2003. From September 1998 to
December 2002, Mr. Quillen was Executive Vice
President Operations of AMCI. While at AMCI, he was
also responsible for the development of AMCIs Australian
properties. Mr. Quillen has over 30 years of
experience in the coal industry starting as an engineer. He has
held senior executive positions in the coal industry throughout
his career, including as Vice President Operations
of Pittston Coal Company, President of Pittston Coal Sales
Corp., Vice President of AMVEST Corporation, Vice
President Operations of NERCO Coal Corporation,
President and Chief Executive Officer of Addington, Inc. and
Manager of Mid-Vol Leasing, Inc.
Kevin S. Crutchfield has served as our Executive Vice
President since our formation in November 2004.
Mr. Crutchfield joined the Alpha management team as the
Executive Vice President of Alpha Natural Resources, LLC and
Vice President of ANR Holdings in March 2003, and has served as
the Executive Vice President of ANR Holdings since November
2003. From June 2001 through January 2003, he was President of
Coastal Coal Company and Vice President of El Paso
Corporation. Prior to joining El Paso, he served as
President of AMVEST Corporation, a coal and gas producer and
provider of related products and services, and held executive
positions at AEI Resources, Inc., most recently as President and
Chief Executive Officer. Before joining AEI Resources, Inc., he
served as the Chairman, President and Chief Executive Officer of
Cyprus Australia Coal Company and held executive operating
management positions with Cyprus in the U.S. before being
relocated to Sydney, Australia in 1997. He worked for Pittston
Coal Company in various operating and executive management
positions from 1986 to 1995 serving most recently as Vice
President Operations prior to joining Cyprus Amax Coal Company.
113
D. Scott Kroh has served as our Executive Vice
President since our formation in November 2004. Mr. Kroh
joined the Alpha management team as the Executive Vice President
of Alpha Natural Resources, LLC in March 2003, and has also
served as the Executive Vice President of ANR Holdings since
November 2003. From June 1989 through February 2003 he served as
President of Tanoma Energys sales and mining company, an
AMCI affiliate located in Latrobe, Pennsylvania. Mr. Kroh
also served as Vice President of AMCI Export from January 1992
until February 2003. Prior to founding Tanoma Energy he served
as Vice President of Sales for Amerikohl Mining Company of
Butler, Pennsylvania from 1980 until May 1989. Mr. Kroh
began his career in the coal business in 1978 as a salesman for
Ringgold Mining Company of Kittanning, Pennsylvania.
David C. Stuebe has served as our Vice President and
Chief Financial Officer since our formation in November 2004.
Mr. Stuebe joined the Alpha management team as the Vice
President and Chief Financial Officer of Alpha Natural
Resources, LLC in October 2003, and has also served as the Vice
President and Chief Financial Officer of ANR Holdings since
November 2003. Mr. Stuebe served from March 2000 to July
2003 as Senior Vice President-Finance and Administration of
Hearth and Home Technologies, Inc., a wholly-owned subsidiary of
HON INDUSTRIES Inc., a leading manufacturer of office systems
and hearth products, and from October 1994 to March 2000 as Vice
President and Chief Financial Officer of the parent, HON
INDUSTRIES Inc. Prior to joining HON, he served as President,
Chief Executive Officer and Director of United Recycling
Industries, Inc., a metals broker, precious metals recycler and
non-ferrous metals producer from 1990 to 1994, as President,
Chief Executive Officer and Director of Auto Specialties
Manufacturing, Inc., a manufacturer of O.E.M. truck and
construction equipment components from 1988 to 1990, and as
Chairman, President and Chief Executive and Chief Financial
Officer of MSL Industries, Inc., a manufacturer and distributor
of fasteners, tubing, roll-form shapes, electric motors,
components for electric utilities and missile components from
1981 to 1987. Mr. Stuebes business background also
includes significant general and financial management positions
with Carpetland U.S.A. and the Scholl Products Group of
Schering-Plough, as well as 13 years of audit experience
with an international public accounting firm.
Michael D. Brown has served as our Vice President since
our formation in November 2004. Mr. Brown joined the Alpha
management team as Vice President of Alpha Natural Resources,
LLC in March 2003, and has also served as Vice President of ANR
Holdings since November 2003. From 2000 through March 2003, he
served as Vice President Development and Technical
Resources for Pittston Coal Company. Prior to this he served as
Pittstons Group Vice President of Metallurgical
Operations, which included all Pittston properties acquired by
Alpha. Mr. Brown served in numerous other executive and
financial positions within Pittston Coal Company including a two
year period as the chief operating officer for Pittstons
affiliated gas and timber companies. Mr. Brown was
affiliated with Pittston Coal from June 1984 until his
employment at Alpha.
Vaughn R. Groves has served as our Vice President and
General Counsel since our formation in November 2004.
Mr. Groves joined the Alpha management team as the Vice
President and General Counsel of Alpha Natural Resources, LLC in
October 2003, and has also served as the Vice President and
General Counsel of ANR Holdings since November 2003. Prior to
that time, he served as Vice President and General Counsel of
Pittston Coal Company from 1996 until joining Alpha, and as
Associate General Counsel of Pittston Coal Company from 1991
until 1996. Before joining Pittston Coal, he was associated with
the law firm of Jackson Kelly PLLC, one of the leading mineral
law firms in the Appalachian region. He is also a mining
engineer and before obtaining his law degree, he worked as an
underground section foreman, construction foreman and mining
engineer for Monterey Coal Company.
Eddie W. Neely has served as our Vice President and
Controller since our formation in November 2004. Mr. Neely
joined the Alpha management team as the Secretary of Alpha
Natural Resources, LLC in August 2002, and has also served as
Vice President and Controller of Alpha Natural Resources, LLC
since March 2003. From August 1999 to August 2002, he served as
Chief Financial Officer of Whites Fresh Foods, Inc., a
family-owned supermarket chain. In August 2001, Whites
Fresh Foods, Inc. filed for reorganization under Chapter 11
of the United States Bankruptcy Code. Prior to joining
Whites Fresh, from October 1997 to August 1999,
Mr. Neely was Controller for Hunt Assisted Living, LLC, a
company
114
that developed, constructed, managed and operated assisted
living facilities for the elderly. Mr. Neely served as
Director of Accounting for The Brinks Company (formerly known as
The Pittston Company) from January 1996 until October 1997 and
held various accounting and finance positions with Pittston Coal
Company and subsidiaries prior to January 1996. Mr. Neely
is a certified public accountant.
E. Linn Draper, Jr. has been a member of our
board of directors since our formation in November 2004.
Mr. Draper joined American Electric Power (AEP), an
electric utility company, as President in 1992, and served as
the Chairman, President and Chief Executive Officer of AEP from
1993 until his retirement in April 2004. Prior to joining AEP,
Mr. Draper worked for Gulf States Utilities Company, an
electric utility company, from 1979 to 1992, serving as the
companys Chairman of the Board, President and Chief
Executive from 1987 to 1992. He serves as a director of Temple
Inland, a holding company with subsidiaries operating in the
corrugated packaging, forest products and financial services
sectors; Trans Canada, a pipeline and power generation company;
and Alliance Data Systems, a data management and transaction
processing company. Mr. Draper is also a non-executive
chairman of NorthWestern Corporation, an electric utility.
Glenn A. Eisenberg has been a member of our board of
directors of since the 2005 annual meeting. Mr. Eisenberg
currently serves as Executive Vice President, Finance and
Administration of The Timken Company, an international
manufacturer of highly engineered bearings, alloy and specialty
steel and components and a provider of related products and
services. Prior to joining The Timken Company in 2002,
Mr. Eisenberg served as President and Chief Operating
Officer of United Dominion Industries, a manufacturer of
proprietary engineered products, from 1999 to 2001, and as the
President Test Instrumentation Segment for United
Dominion Industries from 1998 to 1999. Mr. Eisenberg also
serves as a director of Family Dollar Stores, Inc.
John W. Fox, Jr. has been a member of our board of
directors since our formation in November 2004. Mr. Fox
served as Senior Vice President, Coal Services for Norfolk
Southern Company, a railroad operator, from April 2001 until his
retirement in November 2003, and as Senior Vice President Coal
Marketing from December 1999 to April 2001. Mr. Fox began
his career with a predecessor of Norfolk Western Railroad
Company in 1969.
Alex T. Krueger has been a member of our board of
directors since our formation in November 2004. Mr. Krueger
is a Managing Director of First Reserve Corporation, a private
equity firm focusing on the energy industry, which he joined in
1999. Prior to joining First Reserve Corporation,
Mr. Krueger worked in the Energy Group of Donaldson,
Lufkin & Jenrette from 1997 until 1999.
Mr. Krueger is currently a director of Foundation Coal
Holdings, Inc.
Fritz R. Kundrun has been a member of our board of
directors since our formation in November 2004. Mr. Kundrun
is currently Chairman and Chief Executive Officer of AMCI, a
mining and marketing company, positions he has held since he
co-founded AMCI in 1986. Prior to founding AMCI,
Mr. Kundrun was employed for 26 years by the Thyssen
Group, one of the largest German multinational companies with
interests in steel making and general heavy industrial
production. There he served as Executive Vice President of
Thyssen, Inc., and President of Thyssen Carbometal where his
responsibilities included overseeing the international trading
activities of Thyssen in the Western Hemisphere, Asia and
certain markets in Europe. He also served as Thyssens
chief delegate in Pakistan, Iran and Iraq.
William E. Macaulay has been a member of our board of
directors since our formation in November 2004.
Mr. Macaulay is the Chairman and Chief Executive Officer of
First Reserve Corporation, a private equity firm focusing on the
energy industry, which he joined in 1983. Prior to joining First
Reserve Corporation, Mr. Macaulay was a co-founder of
Meridien Capital Company, a private equity buyout firm. From
1972 to 1982, Mr. Macaulay was with Oppenheimer &
Co., Inc., where he served as Director of Corporate Finance,
with responsibility for investing Oppenheimers capital in
private equity transactions, as a General Partner and member of
the Management Committee of Oppenheimer & Co., as well
as President of Oppenheimer Energy Corporation.
Mr. Macaulay is currently a director of the following SEC
reporting companies: Foundation Coal Holdings, Inc. (as to which
he also serves as Chairman of the Board), Dresser, Inc.,
Dresser-Rand Group Inc. (as to which he also serves as Chairman
of the Board) and Weatherford International, Ltd.
115
Hans J. Mende has been Chairman of our board of directors
since our formation in November 2004. Mr. Mende is
President and Chief Operating Officer of AMCI, a mining and
marketing company, a position he has held since he co-founded
AMCI in 1986. Prior to founding AMCI, Mr. Mende was
employed by the Thyssen Group, one of the largest German
multinational companies with interests in steel making and
general heavy industrial production, in various senior executive
positions. At the time of his departure from Thyssen Group,
Mr. Mende was President of its international trading
company.
Board of Directors
Our board of directors currently consists of eight members. All
of our directors serve one-year terms, with all directors
elected each year. Each current member of our board of directors
was elected or reelected, as applicable, at the annual meeting
of our stockholders held on April 27, 2005, to serve a
one-year term expiring at the annual meeting in 2006 and until
their respective successors are elected and qualified. Each of
these directors had been nominated by the board of directors in
accordance with the provisions of our stockholder agreement,
which contains agreements among our Sponsors and us regarding
the composition of our board of directors. See Certain
Relationships and Related Party Transactions
Transactions in Connection with Internal
Restructuring Stockholder Agreement.
Mr. Macaulay intends to resign from our board of directors
following the effectiveness of the registration statement of
which this prospectus forms a part. In addition,
Mr. Krueger has advised us that he intends to resign as a
director in early 2006 upon our selection of a candidate to
replace him who would satisfy the New York Stock Exchange
(NYSE) independence requirements discussed below, as
selected by our nominating and corporate governance committee.
Under the NYSE rules, we are required to have a majority of
independent directors on our board of directors and to have our
compensation and nominating/ corporate governance committees be
comprised entirely of independent directors by February 14,
2006. In addition, the NYSE rules and the Securities Exchange
Act of 1934 and rules thereunder adopted by the SEC require us
to have our audit committee be comprised entirely of independent
directors by February 14, 2006.
The nominating and corporate governance committee undertook an
annual review of director and director-nominee independence in
March 2005. The purpose of this review was to determine whether
any relationships or transactions involving the directors and
director-nominees, their family members and affiliates were
inconsistent with a determination that the director or director
nominee is independent under the independence standards in the
rules of the NYSE. Based on that review, our board of directors
has determined that each of E. Linn Draper, Jr. Glenn A.
Eisenberg and John W. Fox, Jr. qualify as
independent under the general independence standards
in the NYSE rules.
Committees of the Board of Directors
Our board of directors has three standing committees:
(1) an audit committee, (2) a compensation committee
and (3) a nominating and corporate governance committee.
Audit Committee. The current members of the audit
committee are Messrs. Draper, Eisenberg and Krueger, with
Mr. Eisenberg serving as chairman. Our board of directors
has determined that Mr. Draper is an audit committee
financial expert as that term is defined in
Item 401(h) of
Regulation S-K and
that Messrs. Draper and Eisenberg qualify as
independent members of the audit committee as
defined in the rules of the SEC and NYSE setting forth
independence requirements for public company audit committees.
The audit committee provides assistance to our board of
directors in monitoring the quality, reliability and integrity
of our accounting policies and financial statements, overseeing
our compliance with legal and regulatory requirements and
reviewing the independence, qualifications and performance of
our internal and independent auditors. The audit committee is
also responsible for (1) the appointment, compensation, and
oversight of our independent auditor, (2) approving the
overall scope of the audit and approving any non-audit services
to be performed by the independent auditor, (3) annually
reviewing a report by the independent auditor describing the
firms internal quality control procedures, any material
issues raised by
116
the most recent internal quality control review, or peer review,
of the auditing firm, and all relationships between us and the
independent auditor, (4) discussing the annual audited and
quarterly unaudited financial statements with management and the
independent auditor, (5) discussing the companys
press releases, as well as financial information and earnings
guidance provided to analysts and rating agencies,
(6) reviewing and discussing risk assessment and risk
management policies as well as procedures management has
established to monitor compliance with our Code of Business
Ethics, (7) meeting periodically, but separately, with the
independent auditor, internal auditors and management,
(8) reviewing with the independent auditor any audit
problems or difficulties and managements response,
(9) preparing an audit committee report as required by the
SEC to be included in our annual proxy statement,
(10) establishing policies regarding the companys
hiring of employees or former employees of the independent
auditor, (11) annually reviewing and reassessing the
adequacy of audit committees written charter and
recommending any proposed changes to the board of directors,
(12) reporting regularly to the full board of directors,
(13) conducting an annual performance review and evaluation
of the audit committee, and (14) handling other matters
that are specifically delegated to the audit committee by the
board of directors from time to time.
Compensation Committee. The current members of the
compensation committee are Messrs. Draper, Fox and Krueger,
with Mr. Draper serving as chairman. The compensation
committee and its designated subcommittees are responsible for
(1) reviewing and approving the compensation, including
salary, bonuses and benefits, of our chief executive officer and
other executive officers, (2) reviewing and approving
corporate goals and objectives relevant to the compensation of
executive officers and evaluating their performance in light of
these goals and objectives, (3) reviewing and recommending
to the board of directors executive compensation policies and
practices for our and our subsidiaries executive officers
generally, (4) reviewing director compensation and
recommending any proposed changes the board of directors,
(5) reviewing and recommending to the board of directors,
or approving, any employment contract or similar agreement for
any executive officer, (6) reviewing and consulting with
the chief executive officer regarding matters of key personnel
selection, (7) reviewing and making recommendations to the
board of directors with respect to incentive compensation plans
and equity-based plans, and administering the plans, including
reviewing and approving all awards of shares or options pursuant
to the plans, (8) monitoring compliance with applicable
laws relating to compensation of executive officers,
(9) producing a compensation committee report on executive
compensation as required by the SEC to be included in the
companys annual proxy statement or annual report on
Form 10-K filed
with the SEC, (10) reporting to the full board of directors
following the compensation committees meetings or actions,
(11) conducting an annual performance evaluation of the
compensation committee, and (12) handling other matters
that are specifically delegated to the compensation committee by
the board of directors from time to time. The compensation
committee has established a Section 162(m) subcommittee for
the purpose of complying with
Rule 16b-3 under
the Securities Exchange Act of 1934, and Section 162(m) of
the Internal Revenue Code of 1986, as amended, and has appointed
Mr. Draper and Mr. Fox as the members of the
subcommittee. The subcommittee is authorized to (1) approve
grants of stock options to our executive officers, including our
chief executive officer, in accordance with
Rule 16b-3,
(2) adopt performance goals with respect to
performance-based compensation for executive officers, including
our chief executive officer in accordance with
Section 162(m), (3) determinate whether performance
goals have been met before performance-based compensation is
paid to executive officers in accordance with
Section 162(m), (4) administer our Bonus Plan, Alpha
Coal Management Long-Term Incentive Plan and the Long-Term
Incentive Plan described below under Incentive
Cash Bonus Plan and Long-Term Incentive
Plans and (5) take any other action required to be
performed by a committee or subcommittee of non-employee
directors (pursuant to
Rule 16b-3) and
outside directors (pursuant to Section 162(m)).
Nominating and Corporate Governance Committee. The
current members of the nominating and corporate governance
committee are Messrs. Eisenberg, Fox and Krueger, with
Mr. Fox serving as chairman. The nominating and corporate
governance committee assists the board of directors in
identifying individuals qualified to become board members and
executive officers and selecting, or recommending that the board
select, director nominees for election to the board of directors
and its committees. The
117
nominating and corporate governance committee is also
responsible for (1) developing and recommending governance
policies and procedures to the board of directors,
(2) reviewing conflicts of interest that may affect
directors, (3) monitoring our compliance with corporate
governance practices and policies, (4) leading the board of
directors in its annual review of the boards performance,
(5) making recommendations regarding committee purpose,
structure and operation and (6) overseeing and approving a
management continuity planning process.
Compensation of Our Directors
Directors who are not determined to be independent directors
will receive no additional compensation for serving as
directors. All independent directors will receive
(1) $30,000 as an annual retainer, (2) a $2,000
per-meeting fee for attendance at board meetings, (3) a
$2,000 per-meeting fee for in-person attendance at committee
meetings and a $1,000 per-meeting fee for telephonic attendance
at committee meetings and (4) a $10,000 annual retainer for
service as the chairman of the audit committee and a $2,000
annual retainer for service as the chairman of any other board
committee. Each of the directors is entitled to be reimbursed
for reasonable
out-of-pocket expenses
incurred in connection with attendance at board of directors
meetings or any committee thereof, and customary directors
indemnification. Mr. Draper and Mr. Fox were each
granted an option on February 14, 2005, at an exercise
price of $19.00 per share, and Mr. Eisenberg was
granted an option on April 27, 2005, at an exercise price
of $24.85 per share, in each case pursuant to the Alpha
Natural Resources, Inc. 2005 Long-Term Incentive Plan to
purchase up to 10,000 shares of our common stock, and the
board of directors is considering adopting a broader stock-based
compensation program for directors as well.
Executive Compensation
The following summary compensation table sets forth information
concerning the compensation by us of Michael J. Quillen, our
Chief Executive Officer and President, and our other four most
highly compensated executive officers for each of the last three
completed fiscal years.
Summary Compensation Table
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-Term | |
|
|
|
|
|
|
|
|
Compensation | |
|
|
|
|
|
|
Annual Compensation | |
|
Securities | |
|
|
|
|
|
|
| |
|
Underlying | |
|
All Other | |
Name and Principal Position |
|
Year | |
|
Salary ($) | |
|
Bonus ($)(1)(2) | |
|
Options (#) | |
|
Compensation ($) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Michael J. Quillen
|
|
|
2005 |
|
|
|
434,542 |
|
|
|
(4 |
) |
|
|
|
|
|
|
16,223 |
(5) |
|
Chief Executive Officer and
|
|
|
2004 |
|
|
|
420,004 |
|
|
|
929,409 |
|
|
|
|
|
|
|
45,048 |
(5) |
|
President
|
|
|
2003 |
|
|
|
420,468 |
|
|
|
115,000 |
|
|
|
|
|
|
|
19,023 |
(5) |
Kevin Crutchfield
|
|
|
2005 |
|
|
|
372,484 |
|
|
|
(4 |
) |
|
|
72,905 |
|
|
|
11,633 |
(6) |
|
Executive Vice President(3)
|
|
|
2004 |
|
|
|
360,022 |
|
|
|
600,359 |
|
|
|
|
|
|
|
32,390 |
(6) |
|
|
|
2003 |
|
|
|
311,295 |
|
|
|
100,000 |
|
|
|
|
|
|
|
144,541 |
(6) |
D. Scott Kroh
|
|
|
2005 |
|
|
|
370,392 |
|
|
|
(4 |
) |
|
|
|
|
|
|
13,915 |
(7) |
|
Executive Vice President(3)
|
|
|
2004 |
|
|
|
358,000 |
|
|
|
401,000 |
|
|
|
|
|
|
|
23,944 |
(7) |
|
|
|
2003 |
|
|
|
287,332 |
|
|
|
100,000 |
|
|
|
|
|
|
|
10,367 |
(7) |
David C. Stuebe
|
|
|
2005 |
|
|
|
289,713 |
|
|
|
(4 |
) |
|
|
40,000 |
|
|
|
21,417 |
(8) |
|
Vice President and Chief
|
|
|
2004 |
|
|
|
280,020 |
|
|
|
396,060 |
|
|
|
|
|
|
|
83,688 |
(8) |
|
Financial Officer(3)
|
|
|
2003 |
|
|
|
84,620 |
|
|
|
30,000 |
|
|
|
|
|
|
|
28,375 |
(8) |
Michael D. Brown
|
|
|
2005 |
|
|
|
284,519 |
|
|
|
(4 |
) |
|
|
40,000 |
|
|
|
11,351 |
(9) |
|
Vice President(3)
|
|
|
2004 |
|
|
|
257,696 |
|
|
|
425,143 |
|
|
|
62,841 |
|
|
|
23,334 |
(9) |
|
|
|
2003 |
|
|
|
169,091 |
|
|
|
100,000 |
|
|
|
|
|
|
|
6,224 |
(9) |
See notes on following page.
118
|
|
|
(1) |
We generally pay bonuses in the year following the year in which
they were earned. Unless otherwise noted, bonus amounts
presented represent employee performance bonuses and are
reported for the year in which they were earned, though they may
have been paid in the following year. |
|
|
|
(2) |
Each of the bonuses presented for 2004 include a special bonus
paid in June 2004 to recognize efforts in connection with the
recapitalization of Alpha Natural Resources, LLC in May 2004, a
vacation bonus in the amount of $1,000 and bonuses earned in
2004 under our Annual Incentive Bonus Plan based on the
achievement of specified financial performance, operating and
safety goals for fiscal 2004. |
|
|
|
(3) |
Messrs. Crutchfield, Kroh, Brown and Stuebe joined us on
varying dates in 2003 and the respective compensation for 2003
is reported only from the start date to year end. |
|
|
|
(4) |
A bonus of up to 200% of the participants base salary in
the case of the Chief Executive Officer, and 150% of the
participants base salary in the case of the other named
executive officers, will be payable under our Annual Incentive
Bonus Plan based on the achievement of specified financial
performance, operating and safety goals for fiscal 2005. |
|
|
|
(5) |
Includes our contributions under our 401(k) Plan on behalf of
Mr. Quillen and imputed income of $5,723 and $2,998 in
respect of life insurance in fiscal 2005 and 2004, respectively.
Amounts reflected for 2004 and 2003 also include contributions
to Mr. Quillens account under the Supplemental
Retirement Plan (the SRP) feature of our Amended and
Restated Deferred Compensation Plan in the amount of $31,800 and
$11,023 earned in fiscal 2004 and 2003, respectively, which
amounts were contributed in August 2005 in connection with the
adoption of the SRP. |
|
|
|
(6) |
Includes our contributions under our 401(k) Plan on behalf of
Mr. Crutchfield and (a) imputed income of $1,133 and
$589 in respect of life insurance in fiscal 2005 and 2004,
respectively, and (b) $126,495 of relocation expenses
reimbursed by us and tax
gross-up payments paid
by us in connection with the expense reimbursement in fiscal
2003. Amounts reflected for 2004 and 2003 also include
contributions to Mr. Crutchfields account under the
SRP in the amount of $21,551 and $10,046 earned in fiscal 2004
and 2003, respectively, which amounts were contributed in August
2005 in connection with the adoption of the SRP. |
|
|
|
(7) |
Includes our contributions under our 401(k) Plan on behalf of
Mr. Kroh and imputed income of $4,792 and $1,344 in respect
of life insurance in fiscal 2005 and 2004, respectively. Amounts
reflected for 2004 and 2003 also include contributions to
Mr. Krohs account under the SRP in the amount of
$16,450 and $4,367 earned in fiscal 2004 and 2003, respectively,
which amounts were contributed in August 2005 in connection with
the adoption of the SRP. |
|
|
|
(8) |
Includes our contributions under our 401(k) Plan on behalf of
Mr. Stuebe and (a) imputed income of $10,917 and
$2,938 in respect of life insurance in fiscal 2005 and 2004,
respectively, and (b) $61,949 and $25,836 of relocation
expenses reimbursed by us and tax
gross-up payments paid
by us in connection with the expense reimbursements in fiscal
2004 and 2003, respectively. The amount reflected for 2004 also
includes a contribution to Mr. Stuebes account under
the SRP in the amount of $8,551 earned in fiscal 2004, which
amount was contributed in August 2005 in connection with the
adoption of the SRP. |
|
|
|
(9) |
Includes our contributions under our 401(k) Plan on behalf of
Mr. Brown and imputed income of $851 and $399 in respect of
life insurance in fiscal 2005 and 2004, respectively. The amount
reflected for 2004 also includes a contribution to
Mr. Browns account under the SRP in the amount of
$12,685 earned in fiscal 2004, which amount was contributed in
August 2005 in connection with the adoption of the SRP. |
|
119
Option Grants During 2005
The table below sets forth the options granted to our named
executive officers during 2005.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Individual Grants | |
|
|
|
|
| |
|
Potential Realizable | |
|
|
|
|
% of Total | |
|
|
|
Value at Assumed | |
|
|
Number of | |
|
Options | |
|
|
|
Annual Rate of Stock | |
|
|
Securities | |
|
Granted to | |
|
Exercise | |
|
|
|
Appreciation for | |
|
|
Underlying | |
|
Employees | |
|
Price Per | |
|
|
|
Option Term(4) | |
|
|
Options | |
|
in | |
|
Share | |
|
Expiration | |
|
| |
Name |
|
Granted(1) | |
|
2005(2) | |
|
($/Share) | |
|
Date(3) | |
|
5.0%($) | |
|
10.0%($) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Michael J. Quillen
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Kevin Crutchfield
|
|
|
72,905 |
|
|
|
9.81 |
% |
|
|
19.00 |
|
|
|
2/14/2015 |
|
|
|
871,215 |
|
|
|
2,207,563 |
|
D. Scott Kroh
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
David C. Stuebe
|
|
|
40,000 |
|
|
|
5.38 |
% |
|
|
19.00 |
|
|
|
2/14/2015 |
|
|
|
478,000 |
|
|
|
1,211,200 |
|
Michael D. Brown
|
|
|
40,000 |
|
|
|
5.38 |
% |
|
|
19.00 |
|
|
|
2/14/2015 |
|
|
|
478,000 |
|
|
|
1,211,200 |
|
|
|
|
(1) |
These options were granted under our Long-Term Incentive Plan
and they vest over a five year period, with 20% vesting on each
of the first, second, third, fourth and fifth anniversaries of
the date of grant. |
|
|
|
(2) |
Based on an aggregate of 742,905 shares of our common stock
that are subject to options granted to employees during 2005. |
|
|
|
(3) |
The term of each option granted under the Long-Term Incentive
Plan is generally ten years from the date of grant. Options may
terminate before their expiration date if the option
holders status as an employee is terminated or upon the
option holders death or disability. |
|
|
|
(4) |
The potential realizable values are based on an assumption that
the stock price of our common stock will appreciate at the
annual rate shown, compounded annually, from the date of grant
until the end of the option term. These values do not take into
account amounts required to be paid as income taxes under the
Internal Revenue Code and any applicable state laws or option
provisions providing for termination of an option following
termination of employment, non-transferability or vesting. These
amounts are calculated based on the requirements promulgated by
the SEC and do not reflect estimates of future stock price
growth of our shares of common stock. |
|
2005 Fiscal Year-End Option Values
The following table sets forth information concerning the number
and value of securities underlying unexercised options held by
our named executive officers as of December 31, 2005. None
of our named executive officers exercised any options during
2005.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Number of Securities | |
|
|
|
|
Underlying Unexercised | |
|
Value of Unexercised In-The- | |
|
|
Options at Fiscal | |
|
Money Options at Fiscal | |
|
|
Year-End(#) | |
|
Year-End($)(1) | |
|
|
| |
|
| |
Name |
|
Exercisable | |
|
Unexercisable | |
|
Exercisable | |
|
Unexercisable | |
|
|
| |
|
| |
|
| |
|
| |
Michael J. Quillen
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Kevin Crutchfield
|
|
|
|
|
|
|
72,905 |
|
|
|
|
|
|
|
15,310 |
|
D. Scott Kroh
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
David C. Stuebe
|
|
|
|
|
|
|
40,000 |
|
|
|
|
|
|
|
8,400 |
|
Michael D. Brown
|
|
|
12,568 |
|
|
|
90,273 |
|
|
|
81,441 |
|
|
|
334,169 |
|
|
|
(1) |
Values are calculated based on the closing price of our Common
Stock on December 30, 2005 (i.e., $19.21 per share) less
the applicable exercise price. |
120
Compensation Committee Interlocks and Insider
Participation
Mr. Krueger, a member of our compensation committee, is a
managing director of First Reserve Corporation. Affiliates of
First Reserve Corporation have engaged in certain transactions
with us and our subsidiaries since our inception, as described
more fully in Certain Relationships and Related Party
Transactions. Mr. Krueger also served as a member of
the board of directors of GP Natural Resource Partners LLC,
the general partner of NRP, our largest landlord in 2004 based
on lease, royalty and property tax reimbursement payments, from
December 2003 until his resignation from that position on
December 12, 2005.
Mr. Mende, a member of our compensation committee, is
affiliated with AMCI. AMCI is one of our Sponsors, and AMCI and
certain entities affiliated with AMCI have engaged in certain
transactions with us and our subsidiaries since our acquisition
of U.S. AMCI, as described more fully in Certain
Relationships and Related Party Transactions.
Employment Agreements
Michael J. Quillen. On January 1, 2003, Alpha
Natural Resources, LLC entered into an employment agreement with
Michael J. Quillen to serve as our Chief Executive Officer. On
December 31, 2003, this agreement was assigned to our
indirect wholly-owned subsidiary, Alpha Natural Resources
Services, LLC (Alpha Services). Pursuant to the
employment agreement, as amended, Mr. Quillen receives a
base salary of $420,000 per annum, subject to any increase
as determined by the compensation committee of our board of
directors. In addition, Mr. Quillen is entitled to receive
an annual bonus ranging between 50% and 200% of his then current
base salary, based upon achievement of certain performance and
other goals, a portion of which Mr. Quillen waived with
regard to 2003. Mr. Quillen is also entitled to participate
in our benefit plans.
The initial term of Mr. Quillens employment
agreement, as amended, ends on March 11, 2006, and the
agreement renews for successive annual terms unless terminated
by Mr. Quillen or us in advance of the end of the initial
term or any renewal term. Alpha Services may terminate
Mr. Quillens employment at any time and for any
reason and Mr. Quillen may resign at any time and for any
reason. Under his employment agreement, Mr. Quillen has
agreed to certain non-competition provisions. In consideration
for this non-competition agreement, Alpha Services has agreed to
make payments to Mr. Quillen following the termination of
his employment. If Mr. Quillens employment is
terminated without cause, or Mr. Quillen resigns for
employee cause (as defined in the agreement), Alpha
Services will be required to pay Mr. Quillen his earned but
unpaid salary through the date of termination, and to continue
to pay his then current base salary for the following twelve
months. In addition, Mr. Quillen would be entitled to
receive any bonuses payable for prior years, plus the pro rata
bonus payable for the current year, at the same time as bonuses
are paid to similarly situated employees. Pursuant to the
employment agreement, a resignation by Mr. Quillen
for employee cause includes, among others,
(i) a substantial diminution of his status or
responsibilities, and (ii) his resignation during the
period beginning three months, and ending nine months following
the liquidation or sale by First Reserve of more than 75% of its
ownership in ANR Holdings and affiliates, which would result
from First Reserve holding less than approximately
8,460,921 shares of our common stock after such a sale or
liquidation.
D. Scott Kroh. On January 1, 2003, Alpha
Natural Resources, LLC also entered into an employment agreement
with D. Scott Kroh to serve as our Executive Vice President. On
December 31, 2003, this agreement was assigned to our
wholly-owned subsidiary, Alpha Coal Sales Co., LLC (Alpha
Coal Sales). Pursuant to the employment agreement,
Mr. Kroh receives a base salary of $360,000 per annum,
subject to any increase as determined by the compensation
committee of our board of directors. In addition, Mr. Kroh
is entitled to receive an annual bonus ranging between 50% and
200% of his then current base salary, based upon achievement of
certain performance and other goals, a portion of which
Mr. Kroh waived with regard to 2003. Mr. Kroh is also
entitled to participate in our benefit plans.
The initial term of Mr. Krohs employment agreement,
as amended, ends on March 11, 2006, and the agreement
renews for successive annual terms unless terminated by
Mr. Kroh or us in advance of the end
121
of the initial term or any renewal term. Alpha Coal Sales may
terminate Mr. Krohs employment at any time and for
any reason and Mr. Kroh may resign at any time and for any
reason. Under his employment agreement, Mr. Kroh has agreed
to certain non-competition provisions. In consideration for this
non-competition agreement, Alpha Coal Sales has agreed to make
payments to Mr. Kroh following the termination of his
employment. If Mr. Krohs employment is terminated
without cause, or Mr. Kroh resigns for employee
cause (as defined in the agreement), Alpha Coal Sales will
be required to pay Mr. Kroh his earned but unpaid salary
through the date of termination, and to continue to pay his then
current base salary for the following twelve months. In
addition, Mr. Kroh would be entitled to receive any bonuses
payable for prior years, plus the pro rata bonus payable for the
current year, at the same time as bonuses are paid to similarly
situated employees. Pursuant to the employment agreement, a
resignation by Mr. Kroh for employee cause
includes, among others, (i) a substantial diminution of his
status or responsibilities, and (ii) his resignation during
the period beginning three months and ending nine months
following the liquidation or sale by First Reserve of more than
75% of its ownership in ANR Holdings and affiliates, which would
result from First Reserve holding less than approximately
8,460,921 shares of our common stock after such a sale or
liquidation.
Incentive Cash Bonus Plan
In connection with our Internal Restructuring our board of
directors adopted, and our stockholders approved, our Annual
Incentive Bonus Plan (the Bonus Plan), which was
originally adopted by ANR Holdings in November 2004. The Bonus
Plan is a performance-based incentive bonus plan under which our
designated executive officers and key employees are eligible to
receive cash bonus payments with respect to a specific
performance period (for example, our fiscal year). Bonuses of up
to 200% of a participants base salary are payable under
the Bonus Plan upon the achievement of certain pre-established
performance goals. Performance goals include operational goals
such as safety, productivity, other strategic objectives and
individual performance goals, plus financial measures. Financial
measures that form the basis for performance goals may include
any of the following with respect to us or any of our
subsidiaries, divisions or business units: earnings, operating
earnings, earnings per share, operating earnings per share,
earnings before interest taxes depreciation and amortization,
revenues, stockholders equity, return on equity, return on
assets, return on invested capital, economic value added,
operating margins, cash flow, total stockholder return,
expenses,
debt-to-capital ratio
or market share. The maximum amount that any one participant may
receive under the Bonus Plan in any fiscal year is $10,000,000.
The Bonus Plan is intended to provide an incentive for business
performance, reward contributions towards goals consistent with
our business strategy and enable us to attract and retain highly
qualified executive officers and key employees. The Bonus Plan
will generally be administered by our compensation committee or
a subcommittee of the compensation committee charged with
administering the Bonus Plan, whose determination on all matters
relating to the Bonus Plan will be final and binding. At the
beginning of each year, the committee will select the eligible
participants in the Bonus Plan, establish the performance goals
for the performance period being established in that year for a
participant or group of participants, determine target incentive
bonuses for the participants and, at the end of each performance
period, the committee will certify that the performance goals
have been met with respect to the given performance period. The
compensation committee or subcommittee charged with
administering the Bonus Plan or our board of directors, may
amend, suspend or terminate the Bonus Plan at any time in its
sole discretion.
Retention Plan
On November 10, 2005, the compensation committee of our
board of directors approved a retention compensation plan (the
Retention Plan) in which certain Alpha officers and
key employees designated from time to time by our chief
executive officer will be entitled to participate, including,
among our executive officers, Kevin S. Crutchfield, Executive
Vice President, D. Scott Kroh, Executive Vice President,
David C. Stuebe, Vice President and Chief Financial Officer,
Michael D. Brown, Vice President, Vaughn R. Groves, Vice
President and General Counsel, and Eddie W. Neely, Vice President
122
and Controller. The Retention Plan will entitle participants to
receive cash payments equal to a specified percentage of the
participants annual base salary in the first pay period of
each of 2007, 2008 and 2009 if they are employed by Alpha
Natural Resources, Inc. or its subsidiaries on the applicable
payment date. The amount of the payments under the Retention
Plan will be equal to 20% of the participants 2006 annual
base salary for Retention Plan payments made in the first
payroll period of 2007; 30% of the participants 2007
annual base salary for Retention Plan payments made in the first
payroll period of 2008; and 50% of the participants 2008
annual base salary for Retention Plan payments made in the first
payroll period of 2009. Retention Pan payments are not earned
proportionally through the calendar year and will not be
prorated if a participants employment terminates for any
reason prior to the scheduled payment date.
Management Stock
Pursuant to our stockholder agreement, an aggregate of
672,462 shares of Common Stock held by our executives as of
January 1, 2006 are unvested and subject to forfeiture. The
stockholder agreement provides that an executive holding
unvested shares whose employment is terminated by us for cause,
as defined in the stockholder agreement, or who voluntarily
terminates his employment will forfeit all of the unvested
shares if the termination is prior to December 31, 2006.
The stockholder agreement also provides that an executive
holding unvested shares whose employment is terminated by us
without cause, or due to retirement, death or disability, will
become vested upon termination in a percentage of the total
shares initially subject to vesting equal to the number of full
calendar months then elapsed since December 31, 2004
divided by 24. The stockholder agreement further provides that
vesting of all unvested shares will accelerate upon a change of
control of the Company, as defined in the stockholder agreement.
Long-Term Incentive Plans
|
|
|
Alpha Coal Management Amended and Restated 2004 Long-Term
Incentive Plan |
In November 2004, the board of directors of Alpha Coal
Management adopted, and its members approved, the Alpha Coal
Management LLC 2004 Long-Term Incentive Plan (the Alpha
Coal Management Long-Term Incentive Plan) to provide
equity incentive compensation to those key employees and others
who make significant contributions to the strategic and
long-term performance objectives and growth of Alpha. On
November 10, 2004, Alpha Coal Management granted options to
purchase 800,000 units of Alpha Coal Management to 22
members of Alphas management team under the Alpha Coal
Management Long-Term Incentive Plan. Among our executive
officers, only Michael D. Brown, Vaughn R. Groves and Eddie W.
Neely were granted options under the Alpha Coal Management
Long-Term Incentive Plan. These options vest over a period of
five years (with accelerated vesting upon a change of control of
Alpha) and have a term of ten years. In connection with this
grant of options, Alpha Coal Management entered into a letter
agreement with ANR Holdings pursuant to which ANR Holdings
agreed to issue to Alpha Coal Management additional membership
interests representing sharing ratios in an aggregate amount
equal to 1% of the outstanding membership interests upon
exercise of awards granted by Alpha Coal Management under the
Alpha Coal Management Long-Term Incentive Plan. Pursuant to the
terms of the Internal Restructuring Agreement, this plan was
amended and restated, the outstanding options to purchase units
of Alpha Coal Management were automatically converted into
options to purchase shares of our common stock and we assumed
the obligations of Alpha Coal Management pursuant to this plan.
As of January 1, 2006, there are outstanding under the plan
options to purchase an aggregate of 510,688 shares of our
common stock (the maximum number of shares currently available
for awards under the plan) at an exercise price of
$12.73 per share. No additional options or other awards
will be granted under the plan. The number of shares of our
common stock reserved pursuant to the plan will be subject, at
the discretion of our board of directors (or the committee if so
empowered), to adjustment as a result of stock splits, stock
dividends and similar changes in our common stock.
Following our assumption of the Amended and Restated Alpha Coal
Management LLC 2004 Long-Term Incentive Plan in connection with
the Internal Restructuring, the plan is administered on the same
123
basis and subject to the same regulation as our Long-Term
Incentive Plan as described under Alpha Natural Resources,
Inc. Long-Term Incentive Plan.
|
|
|
Alpha Natural Resources, Inc. Long-Term Incentive
Plan |
In connection with the Internal Restructuring, we adopted, and
our stockholders approved, the Alpha Natural Resources, Inc.
Long-Term Incentive Plan (the Long-Term Incentive
Plan). The principal purpose of the Long-Term Incentive
Plan is to attract, motivate, reward and retain selected
employees, consultants and directors through the granting of
stock-based compensation awards. The Long-Term Incentive Plan
provides for a variety of awards, including non-qualified stock
options, incentive stock options (within the meaning of
Section 422 of the Code), stock appreciation rights,
restricted stock awards, dividend equivalents, performance-based
awards and other stock-based awards.
Administration. The Long-Term Incentive Plan is
administered by our board of directors, and the board has
delegated administration to the compensation committee which has
further delegated administration to the Section 162(m)
subcommittee of the compensation committee. The board or the
committee may in certain circumstances delegate administration
of the plan to one or more of Alphas officers. The board
of directors or the committee, if so empowered, has the power to
interpret the Long-Term Incentive Plan and to adopt rules for
the administration, interpretation and application of the plan
according to its terms.
Grant of Awards; Shares Available for Awards. Certain
employees, consultants and directors are eligible to be granted
awards under the plan. The board of directors, or the committee
if so empowered, will determine who will receive awards under
the plan, as well as the form of the awards, the number of
shares underlying the awards, and the terms and conditions of
the awards consistent with the terms of the plan.
The total number of shares of our common stock initially
available for issuance or delivery under our Long-Term Incentive
Plan is 3,338,841 shares, and the maximum number of shares
that may be subject to awards made to any one plan participant
in any fiscal year will be 2,000,000 shares. As of
January 1, 2006, we have issued 12,000 shares of our
common stock pursuant to restricted stock awards under the
Long-Term Incentive Plan, and 742,905 shares of our common
stock are subject to outstanding options granted under the
Long-Term Incentive Plan. The number of shares of our common
stock issued or reserved pursuant to the Long-Term Incentive
Plan is subject, at the discretion of the board of directors (or
the committee if so empowered), to adjustment as a result of
stock splits, stock dividends and similar changes in our common
stock.
Stock Options. The Long-Term Incentive Plan permits the
board of directors, or the committee if so empowered, to grant
participants incentive stock options, which qualify for special
tax treatment in the United States, as well as non-qualified
stock options. The board, or the committee if so empowered, will
establish the duration of each option at the time it is granted,
with a maximum ten-year duration for incentive stock options,
and may also establish vesting and performance requirements that
must be met prior to the exercise of options. Stock option
grants (other than incentive stock option grants) also may have
exercise prices that are less than, equal to or greater than the
fair market value of our common stock on the date of grant.
Incentive stock options must have an exercise price that is at
least equal to the fair market value of our common stock on the
date of grant.
Stock option grants may include provisions that permit the
option holder to exercise all or part of the holders
vested options, or to satisfy withholding tax liabilities, by
tendering shares of common stock already owned by the option
holder for at least six months (or another period consistent
with the applicable accounting rules) with a fair market value
equal to the exercise price.
Stock Appreciation Rights. The board of directors, or the
committee if so empowered, may also grant stock appreciation
rights, either alone or in tandem with underlying stock options
or other awards, which will be exercisable upon the occurrence
of certain contingent events. Stock appreciation rights entitle
the holder upon exercise to receive an amount in any combination
of cash, shares of our common
124
stock (as determined by the committee) equal in value to the
excess of the fair market value of the shares covered by the
right over the exercise price of the stock appreciation right,
or other securities or property of Alpha.
Other Equity-Based Awards. In addition to stock options
and stock appreciation rights, the board of directors, or the
committee if so empowered, may also grant to certain employees,
consultants and directors shares of restricted stock, restricted
stock rights, dividend equivalents, performance-based awards or
other stock-based awards, with terms and conditions as the board
of directors (or, if applicable, the committee) may, pursuant to
the terms of the Long-Term Incentive Plan, establish. The
Long-Term Incentive Plan also allows awards to be made in
conjunction with a participants election to defer
compensation. The maximum amount that any one participant may
receive with respect to awards under the Long-Term Incentive
Plan in any fiscal year in cash or any other form of property
other than shares of our common stock is $10,000,000.
Change-in-Control
Provisions. In connection with the grant of an award, the
board of directors, or the committee if so empowered, may
provide that, in the event of a change in control of Alpha, any
outstanding awards that are unexercisable or otherwise unvested
will become fully vested and immediately exercisable. In
addition, the committee may, in its sole discretion, provide for
the termination of an award upon the consummation of the change
in control and the payment of a cash amount in exchange for the
cancellation of an award, and/or the issuance of substitute
awards that will substantially preserve the otherwise applicable
terms of any affected award.
Amendment and Termination. Our board of directors, or the
committee if so empowered, may adopt, amend and rescind rules
relating to the administration of the Long-Term Incentive Plan,
and amend, suspend or terminate the Long-Term Incentive Plan,
but no amendment will be made that adversely affects in a
material manner any rights of the holder of any award without
the holders consent, other than amendments that are
necessary to permit the granting of awards in compliance with
applicable laws. We have attempted to structure the Long-Term
Incentive Plan so that remuneration attributable to stock
options and other awards will not be subject to a deduction
limitation contained in Section 162(m) of the Code.
125
PRINCIPAL AND SELLING STOCKHOLDERS
The following table and accompanying footnotes show information
regarding the beneficial ownership of our common stock before
and after this offering, for:
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each person who is known by us to own beneficially more than 5%
of our common stock; |
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each of the selling stockholders; |
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each member of our board of directors and each of our named
executive officers; and |
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all members of our board of directors and our executive officers
as a group. |
The number of shares and percentage of beneficial ownership
before and after the offering set forth below are based on
64,420,414 shares of our common stock issued and
outstanding as of January 1, 2006.
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Shares Beneficially Owned After This Offering | |
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Shares Beneficially | |
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Assuming the | |
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Assuming the | |
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Owned Prior to | |
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Shares to | |
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Underwriters Option | |
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Underwriters Option | |
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This Offering | |
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be | |
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is Not Exercised* | |
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is Exercised in Full* | |
Name and Address |
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Sold in | |
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of Beneficial Owner(1) |
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Number | |
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Percent | |
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This Offering | |
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Number | |
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Percent | |
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Number | |
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Percent | |
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First Reserve GP IX, Inc.(2)
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13,998,911 |
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21.73 |
% |
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12,151,494 |
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1,847,417 |
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2.87 |
% |
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0 |
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First Reserve Fund IX, L.P.(2)
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12,462,992 |
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19.35 |
% |
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10,818,268 |
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1,644,724 |
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2.55 |
% |
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0 |
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ANR Fund IX Holdings, L.P.(2)
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1,535,919 |
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2.38 |
% |
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1,333,226 |
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202,693 |
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0.31 |
% |
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0 |
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Fritz R. Kundrun(3)
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11,351,896 |
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17.62 |
% |
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0 |
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11,351,896 |
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17.62 |
% |
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11,351,896 |
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17.62 |
% |
Hans J. Mende(3)
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11,351,896 |
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17.62 |
% |
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0 |
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11,351,896 |
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17.62 |
% |
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11,351,896 |
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17.62 |
% |
Madison Capital Funding LLC(4)
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164,616 |
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0.26 |
% |
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164,616 |
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0 |
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0 |
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Michael J. Quillen(5)
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715,830 |
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1.11 |
% |
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0 |
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715,830 |
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1.11 |
% |
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715,830 |
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1.11 |
% |
Kevin S. Crutchfield(6)
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240,510 |
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0.37 |
% |
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0 |
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240,510 |
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0.37 |
% |
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240,510 |
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0.37 |
% |
D. Scott Kroh(7)
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1,705,935 |
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2.65 |
% |
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0 |
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1,705,935 |
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2.65 |
% |
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1,705,935 |
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2.65 |
% |
Michael D. Brown(8)
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155,060 |
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0.24 |
% |
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0 |
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155,060 |
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0.24 |
% |
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155,060 |
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0.24 |
% |
David C. Stuebe(9)
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159,297 |
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0.25 |
% |
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0 |
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159,297 |
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0.25 |
% |
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159,297 |
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0.25 |
% |
E. Linn Draper, Jr.(10)
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2,000 |
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0.00 |
% |
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0 |
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2,000 |
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0.00 |
% |
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2,000 |
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0.00 |
% |
Glenn A. Eisenberg(10)
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0 |
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0 |
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0 |
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0 |
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John W. Fox, Jr.(10)
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12,000 |
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0.02 |
% |
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0 |
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12,000 |
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0.02 |
% |
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12,000 |
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0.02 |
% |
Alex T. Krueger(11)
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0 |
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0 |
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0 |
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0 |
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William E. Macaulay(11)
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0 |
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0 |
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0 |
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0 |
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All executive officers and directors as a group (14 persons)(12)
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13,051,203 |
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20.24 |
% |
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0 |
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13,051,203 |
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20.24 |
% |
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13,051,203 |
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20.24 |
% |
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* |
The selling stockholders will grant the underwriters an option
to purchase up to an additional 1,847,417 shares in this
offering. |
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(1) |
The shares of our common stock beneficially owned are reported
on the basis of regulations of the SEC governing the
determination of beneficial ownership of securities. Under the
rules of the SEC, a person is deemed to be a beneficial
owner of a security if that person has or shares voting
power, which includes the power to vote or direct the voting of
such security, or investment power, which includes the power to
dispose of or to direct the disposition of such security. A
person is also deemed to be a beneficial owner of any securities
of which that person has a right to acquire beneficial ownership
within 60 days. Securities that can be so acquired are
deemed to be outstanding for purposes of computing such
persons ownership percentage, but not for purposes of
computing any other persons percentage. Under these rules,
more than one person may be deemed beneficial owner of the same
securities and a person may be deemed to be a beneficial owner
of securities as to which such person has no economic interest.
Except as otherwise indicated in these footnotes, each of the
beneficial owners has, to our knowledge, sole voting and
investment power with respect to the indicated shares of common
stock. In accordance with the beneficial ownership rules of the |
126
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SEC, the table does not reflect an aggregate of 270,869 shares
of common stock reserved for issuance upon the exercise of
outstanding options not exercisable within 60 days held by
certain of our directors and executive officers under our
Long-Term Incentive Plan and under the Alpha Coal Management
Long-Term Incentive Plan that we assumed in connection with the
Internal Restructuring. |
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(2) |
The shares of our common stock shown for First Reserve GP IX,
Inc. consist of shares beneficially owned by First Reserve
Fund IX, L.P. and by ANR Fund IX Holdings, L.P. First
Reserve GP IX, L.P. is the general partner of each of First
Reserve Fund IX, L.P. and ANR Fund IX Holdings, L.P.
First Reserve GP IX, Inc. is the general partner of First
Reserve GP IX, L.P. First Reserve Corporation is the investment
advisor to both First Reserve Fund IX, L.P. and ANR
Fund IX Holdings, L.P. The address of First Reserve
Corporation, First Reserve GP IX, Inc., First Reserve GP IX,
L.P., First Reserve Fund IX, L.P. and ANR Fund IX
Holdings, L.P. is One Lafayette Place, Greenwich, CT 06830. |
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(3) |
Reflects beneficial ownership through shared voting and
investment power over shares of common stock held by the
following entities affiliated with the owners of AMCI, which
entities own of record the following number of shares of our
Common Stock as of January 1, 2006: AMCI Holdings, Inc.
(2,739,684 shares), Beta Resources II, LLC (1,126,250
shares), Creekside II, Inc. (1,732,195 shares), Laurel
Energy II, LP (775,168 shares), Madison Mining
Company II, LLC (124,754 shares), Redbank II, Inc.
(675,727 shares), Tanoma Energy II, Inc. (3,087,021
shares), and Vollow Resources II, LLC (1,091,097 shares).
AMCI Holdings, Inc. is the indirect owner of 100% of
Creekside II, Inc. and Redbank II, Inc., and may be deemed
to have beneficial ownership of the shares held by those
entities. The address for each of the above entities and
Messrs. Mende and Kundrun is c/o American Metals & Coal
International, Inc., One Energy Place, Suite 1000, Latrobe,
PA 15650, Attention: Hans J. Mende, President. |
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(4) |
Madison Capital Funding LLC (Madison Capital) is an
affiliate of registered broker-dealers NYLIFE Securities Inc.
and NYLIFE Distributors LLC. In March 2003, Madison Capital
acquired membership interests of ANR Holdings, LLC for its own
account and not for resale in connection with any distribution
within the meaning of the Securities Act. Madison Capitals
membership interest in ANR Holdings was exchanged, in February
2005, for promissory notes and shares of our common stock in
connection with the Internal Restructuring that preceded our
initial public offering. Madison Capital did not have any
arrangements or understandings with any person to distribute our
securities at the time it acquired membership interests in ANR
Holdings, LLC or at the time it acquired shares of our common
stock in connection with our Internal Restructuring. |
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(5) |
Includes beneficial ownership of 225,831 unvested shares as
described under Management Management
Stock. The address for Mr. Quillen is c/o Alpha
Natural Resources, Inc., One Alpha Place, P.O. Box 2345,
Abingdon, Virginia 24212. |
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(6) |
Includes beneficial ownership of 112,914 unvested shares as
described under Management Management
Stock. Also includes 14,581 shares issuable upon exercise
of options held by Mr. Crutchfield that are exercisable
within 60 days. The address for Mr. Crutchfield is
c/o Alpha Natural Resources, Inc., One Alpha Place, P.O.
Box 2345, Abingdon, Virginia 24212. |
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(7) |
Includes beneficial ownership of 90,330 unvested shares as
described under Management Management
Stock. Also includes beneficial ownership of one-third of
the shares of common stock held as of January 1, 2006
directly by each of Tanoma Energy II, Inc. and Madison
Mining Company II, LLC, and 44.3% of the shares held
directly by Laurel Energy, L.P. through Mr. Krohs
investment power over these shares. Mr. Kroh disclaims
beneficial ownership of all other shares of common stock held by
the entities listed in the previous sentence. The address for
Mr. Kroh is c/o Alpha Natural Resources, Inc., One
Alpha Place, P.O. Box 2345, Abingdon, Virginia 24212. |
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(8) |
Includes beneficial ownership of 67,246 unvested shares as
described under Management Management
Stock. Also includes 20,568 shares issuable upon exercise
of options held by Mr. Brown that are exercisable within
60 days. The address for Mr. Brown is c/o Alpha
Natural Resources, Inc., One Alpha Place, P.O. Box 2345,
Abingdon, Virginia 24212. |
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(9) |
Includes beneficial ownership of 67,752 unvested shares as
described under Management Management
Stock. Also includes 8,000 shares issuable upon exercise
of options held by Mr. Stuebe that are exercisable within
60 days. The address for Mr. Stuebe is c/o Alpha
Natural Resources, Inc., One Alpha Place, P.O. Box 2345,
Abingdon, Virginia 24212. |
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(10) |
Includes 2,000 shares issuable upon exercise of options held by
Mr. Draper, and 2,000 shares issuable upon exercise of
options held by Mr. Fox, that are exercisable within
60 days. The address for Messrs. Draper, Eisenberg and
Fox is c/o Alpha Natural Resources, Inc., One Alpha Place,
P.O. Box 2345, Abingdon, Virginia 24212. |
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(11) |
Mr. Krueger is an executive officer of First Reserve G.P.
IX, Inc. and disclaims beneficial ownership of any shares owned
by such entity or its affiliates. Mr. Macaulay is the Chief
Executive Officer and a member of the board of directors of
First Reserve G.P. IX, Inc. and disclaims beneficial ownership
of any shares owned by such entity or its affiliates. The
address of Messrs. Krueger and Macaulay is c/o First
Reserve Corporation, One Lafayette Place, Greenwich, CT 06830. |
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(12) |
See notes (3) and (5) through (11) above. Also includes an
additional 10,180 shares issuable upon exercise of options that
are exercisable within 60 days held by our executive
officers who are not separately listed in this table. |
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CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
Loans from First Reserve
We were formed and wholly owned by First Reserve, one of our
Sponsors, in 2002. As part of our formation and our acquisition
of our Predecessor in December 2002, First Reserve loaned us
$24.0 million for which we incurred interest expense of
$2.6 million during 2003. The loan was contributed to our
capital in 2003.
On November 17, 2003, First Reserve loaned us
$30.0 million to fund the purchase price of the Mears
acquisition. We repaid all outstanding principal and interest on
this loan during December 2003.
Payments by Affiliates of AMCI to Mr. Quillen
In connection with our acquisition of U.S. AMCI
(U.S. AMCI), certain affiliates of AMCI entered
into an agreement with Michael J. Quillen, a member of our board
of directors and our President and Chief Executive Officer,
pursuant to which they paid Mr. Quillen $194,000 in 2003,
$250,000 in 2004 and $250,000 in 2005 in respect of compensation
deferred from his prior employment with U.S. AMCI. The
purpose of this agreement was in part to recognize
Mr. Quillens efforts in connection with our
acquisition of U.S. AMCI.
Also at the time of the U.S. AMCI acquisition and in
further recognition of Mr. Quillens efforts in
connection with the development and growth of U.S. AMCI
over the previous five years and the contribution of
U.S. AMCI to us, Hans J. Mende and Fritz R. Kundrun, who
are members of our board of directors, and D. Scott Kroh, our
Executive Vice President (the AMCI Owners) entered
into an incentive agreement with Mr. Quillen. Under this
incentive agreement, as amended, the AMCI Owners agreed to
compensate Mr. Quillen upon our repayment of indebtedness
that we incurred to our stockholders in connection with our
Internal Restructuring, any sale or disposition by the AMCI
Owners of our common stock received by them in the Internal
Restructuring or any merger or consolidation of us with a third
party or sale of all or substantially all of our assets to an
unaffiliated party. The amount of the payment to
Mr. Quillen under this incentive agreement will be equal to
5% of the net amount, if any, by which the value of the
consideration received by the AMCI Owners exceeds an agreed upon
net value of their interest in ANR Holdings at the time of the
U.S. AMCI acquisition, minus 5% of certain of the AMCI
Owners expenses for the transaction for which
Mr. Quillen is paid. Mr. Quillen received a payment of
approximately $22.9 million under the incentive agreement
as a result of our repayment of indebtedness to our
stockholders, including the AMCI Owners, in connection with our
initial public offering. The incentive agreement terminates on
the earlier to occur of March 11, 2010 and one year after
the date Mr. Quillen ceases to be an officer or employee of
ANR Holdings or any of its subsidiary or affiliated companies.
In the event that the AMCI Owners have not transferred all of
our common stock received by them in the Internal Restructuring
in one or more transactions of the type listed above by
March 11, 2010, the AMCI Owners have agreed to pay
Mr. Quillen consideration equal to 5% of the amount by
which the agreed or appraised fair market value of common stock
on that date exceeds the agreed upon value referred to above.
Transactions with Mr. Kroh
Mr. Kroh is a 50% owner of Robindale Energy Services, Inc.
(Robindale), which is engaged in the business of
waste coal sales and related businesses in Pennsylvania. From
time to time, Robindale has sold and purchased and may in the
future sell or purchase waste coal and related products to or
from us. During 2003, 2004 and 2005, we paid an aggregate of
$0.2 million, $0.8 million and $1.0 million,
respectively, to Robindale as payment for trucking services and
waste coal. During 2004 and 2005, we had sales of
$0.2 million and $0.5 million, respectively, to
Robindale. We have agreed that Mr. Krohs continued
relationship with Robindale will not cause a breach of his
employment agreement with us, and Mr. Kroh has agreed that
he will not participate in any decisions to enter into any
transactions that might be proposed between Robindale and Alpha.
129
Office Lease from Related Parties
We lease office space in Latrobe, Pennsylvania from the KMKT
Partnership, which is 25% owned by Mr. Kroh, 25% owned by
Mr. Mende, and 25% owned by Mr. Kundrun. The initial
term of the lease extends through March 31, 2007 and
provides for rental payments of $15,500 per month.
Loan to Executives
In connection with the hiring in October 2003 of David Stuebe,
our Vice President and Chief Financial Officer, we extended to
Mr. Stuebe a $100,000 relocation loan bearing interest at a
rate of 6%. Mr. Stuebe repaid all outstanding principal and
interest on this loan on March 31, 2004. In connection with
the hiring in February 2003 of Kevin Crutchfield, our Executive
Vice President, we extended to Mr. Crutchfield a $79,600
relocation loan bearing interest at a rate of 6.25%.
Mr. Crutchfield repaid all outstanding principal and
interest on this loan during 2003.
Coal Transaction with Foundation
On October 26, 2004, we agreed to purchase an aggregate of
500,000 tons of coal from subsidiaries of Foundation, with an
option to purchase up to 25,000 tons more upon agreement of the
parties. We paid Foundation an aggregate of $34.1 million
during 2005 in connection with coal purchases pursuant to this
agreement. The coal is deliverable in monthly installments
during the period from January 2005 through March 2006.
Messrs. Mende, Krueger and Macaulay are members of our
board of directors who also serve as directors of Foundation.
First Reserve and entities affiliated with AMCI beneficially own
an aggregate of 12.6% of the outstanding shares of
Foundations common stock as of September 30, 2005.
Coal Transactions with the AMCI Parties
During 2003, 2004 and 2005, we were parties to coal purchase and
sale transactions involving entities affiliated with AMCI valued
at approximately $14.8 million, $68.3 million and
$136.8 million, respectively. We are obligated to deliver
300,000 firm tons and 200,000 optional tons of coal during April
2005 through March 2006 to AMCI Metall & Kohle AG, a
company owned by Mr. Mende and Mr. Kundrun, under an
arrangement whereby we sell coal to AMCI Metall & Kohle
AG at a price that is $1.00 per metric ton less than the
price at which AMCI Metall & Kohle AG resells the coal
to an international customer. Other than this arrangement with
AMCI Metall & Kohle AG for coal shipped during April
2005 through March 2006, since our acquisition of U.S. AMCI
we have not paid or agreed to pay any commission or fee to
Mr. Mende or Mr. Kundrun or any entities affiliated
with AMCI in connection with our coal transactions with entities
affiliated with AMCI.
Mr. Krueger and Mr. Macaulay are members of the board
of directors of AMCI Holdings Australia PTY LTD, one
of the entities affiliated with AMCI in which an affiliate of
First Reserve Fund X, L.P. holds a 49% equity interest and
with which we have engaged in coal purchase and sale
transactions that are included within the coal purchase and sale
transactions described in the first sentence of the preceding
paragraph.
Transactions in Connection with the U.S. AMCI
Acquisition
The Contribution Agreement. In connection with our
acquisition of U.S. AMCI, we entered into a contribution
agreement with certain affiliates of AMCI (the AMCI
Parties) and First Reserve, pursuant to which the AMCI
Parties agreed to contribute their North American coal
operations (including working capital) to us in exchange for
$53.9 million in cash, the issuance by ANR Holdings of
44.3473% of its common sharing ratios, and 44.4903% of its
preferred sharing ratios, and the assumption by certain of our
subsidiaries of various liabilities. Messrs. Mende, Kundrun
and Kroh control the AMCI Parties. The contribution agreement
included customary seller representations and warranties,
customary covenants and other agreements among the AMCI parties,
First Reserve and us and provides for indemnification for losses
relating to specified events, circumstances and matters. The
indemnification arrangements permit, under certain
circumstances, the transfer by certain of the AMCI Parties to
First Reserve of membership
130
interests in ANR Holdings (shares of our common stock after
giving effect to the Internal Restructuring) to compensate for
indemnified losses.
The contribution agreement with the AMCI Parties also included a
number of post-closing matters in addition to the
indemnification agreement referred to above. The following
summarizes the principal terms of these matters:
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The AMCI Parties established an escrow of $2.8 million in
favor of us and First Reserve in respect of certain retiree
medical liabilities retained by the AMCI Parties. This escrow
arrangement was eliminated as part of the Internal Restructuring. |
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Certain of the AMCI Parties entered into a pledge agreement with
First Reserve under which these persons pledged to First Reserve
all of their membership interests in ANR Holdings to secure
their obligation under the contribution agreement to discharge
certain retiree medical liabilities retained by the AMCI
Parties. This pledge agreement was terminated in connection with
the Internal Restructuring. |
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The AMCI Parties gave First Reserve the right to purchase from
them additional ANR Holdings membership interests having a fair
market value of up to $7.5 million, at a purchase price
equal to 75% of the fair market value, in the event payments are
required to be made under the escrow agreement to satisfy the
AMCI parties indemnification obligations under the
contribution agreement to discharge certain retiree medical
liabilities retained by the AMCI Parties. This right to purchase
was terminated in connection with the Internal Restructuring. |
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We reimbursed AMCI $2.0 million in transaction costs
related to the acquisitions of our Predecessor and Coastal Coal
Company. |
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We entered into an agreement with certain of the AMCI Parties
under which they granted us the right to acquire AMCIs
wholly-owned subsidiary, AMCI Export Corporation, an export
trading company. These rights expired on September 11,
2004. We also entered into an agreement with Messrs. Mende,
Kundrun and Kroh and others that gives us the option to acquire
an ocean going port in Nova Scotia from them for
$2.0 million plus the amount of follow-on investments made
in the port after the date of the agreement, payable in shares
of our common stock. This purchase option expired on
March 11, 2005. We also have a right of first refusal that
expires on March 11, 2008 to acquire the port if the owners
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We paid $35.0 million for the working capital of
U.S. AMCI, subject to a post-closing audit. On
September 13, 2004, we, First Reserve and the AMCI Parties
agreed that the net working capital actually acquired was
approximately $34.1 million and the AMCI Parties paid the
difference of $0.9 million to us. We further agreed that
the AMCI Parties would be entitled to any refund of, and
obligated to make any payment of, all federal black lung excise
taxes of the companies contributed by the AMCI Parties to us,
estimated to be $0.1 million, but only insofar as the taxes
related to pre-closing or straddle periods ending on or prior to
the closing date of the U.S. AMCI acquisition. |
Solomons Mining Company. In conjunction with the
U.S. AMCI acquisition, we agreed with the AMCI Parties to
operate Solomons Mining Company (Solomons), one of
the companies included in U.S. AMCI, for the account of the
AMCI Parties until the time Solomons could be sold, and the AMCI
parties agreed to indemnify us for all liabilities associated
with the operation of Solomons. We also agreed that, upon the
disposition of Solomons, we would pay to the AMCI Parties
$5.0 million in cash (which we withheld in connection with
the contribution transaction to fund Solomons operating
losses), plus the net proceeds of the sale of Solomons, plus the
cumulative profits or less the cumulative operating losses of
Solomons from the date of our acquisition of U.S. AMCI to
the date of sale of Solomons, less the actual costs incurred by
ANR Holdings in managing Solomons. On September 2, 2003,
substantially all of the assets of Solomons and cash were
transferred to the lessor of Solomons mining properties in
connection with the settlement of a lease dispute with the
lessor. At that time, ANR Holdings, First Reserve and the AMCI
Parties agreed that Solomons would advance to the lessor for the
account of the AMCI Parties an aggregate of $3.1 million in
cash in installments, by applying a portion of the withheld
funds and a portion
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of the tax distributions that we would otherwise have made to
the AMCI Parties under the ANR Holdings company agreement. The
AMCI Parties also agreed to provide to us an additional
$1.0 million to be used to pay operating expenses. This
agreement also provides that should the AMCI Parties fail to
perform any of their payment obligations, then First Reserve
would have the right (but not the obligation) to purchase
membership interests in ANR Holdings held by the AMCI Parties
having a fair market value, as of March 11, 2003, equal to
the payment the AMCI Parties failed to make. This right to
purchase was terminated in connection with the Internal
Restructuring.
As part of the arrangement to operate Solomons, we entered into
an agreement to purchase from a third party and for the account
of the AMCI Parties 350,000 tons of coal at various times from
April 2004 through November 2005 (the Coal Supply
Agreement). On April 22, 2004, ANR Holdings, First
Reserve and the AMCI Parties entered into an agreement (the
April 2004 Agreement), under which we take the coal
to be delivered under the Coal Supply Agreement and pay to the
AMCI Parties the difference between the agreed fair market value
of the coal as of the date of the April 2004 Agreement
($54.50 per ton), and the price to be paid to the third
party under the Coal Supply Agreement ($34.50 per ton). We
have withheld up to 40% of the net proceeds to fund
Solomons reclamation obligations and any other
Solomons liabilities for which the AMCI Parties agreed to
provide indemnification. With the exception of reclamation
obligations and any future claims by the lessor referred to
above, the amounts withheld will be our exclusive recourse
against the AMCI Parties for this indemnification. As of
November 30, 2005, the third party had shipped
approximately 388,000 tons of coal pursuant to the Coal
Supply Agreement. Because the third party has satisfied its
delivery obligations under the Coal Supply Agreement, the AMCI
Parties will not be obligated to fund certain of the payments
that could otherwise be due to ANR Holdings under the
September 2, 2003 agreement with ANR Holdings and First
Reserve. We believe that the sources of indemnification
available to us, which include the amounts withheld under the
Coal Supply Agreement and recourse to certain of the AMCI
Parties for matters related to reclamation and future claims by
the lessor, will be sufficient to satisfy all claims expected to
arise related to Solomons. As of November 30, 2005, the
AMCI Parties owed us $2.3 million for reclamation expenses
in excess of collections under the Coal Supply Agreement.
Transactions with NRP
NRP is our largest landlord based on the aggregate of
$16.0 million, $20.2 million and $22.1 million
that we paid it in lease, royalty and property tax reimbursement
and royalty payments during 2003, 2004 and 2005, respectively.
In an unrelated transaction, in December 2003, Alex Krueger, a
member of our board of directors, was appointed as a member of
the board of directors of GP Natural Resource Partners, LLC, the
general partner of NRP, and First Reserve became a substantial
equity owner of NRP. First Reserve sold all of its equity
ownership in NRP on December 9, 2005 and Mr. Krueger
resigned from the board of directors of NRPs general
partner on December 12, 2005. We believe the production and
minimum royalty rates contained in our leases with NRP are
consistent with current market royalty rates.
Investment in Excelven Pty Ltd
In August 2004, we and the AMCI Parties entered into an
agreement with Excelven Pty Ltd, pursuant to which we agreed to
acquire a 24.5% interest in Excelven for a purchase price of
$5.0 million in cash, and the AMCI Parties agreed to
acquire a 24.5% interest in Excelven for a purchase price of
$5.0 million in cash. Excelven, through its subsidiaries,
owns the rights to the Las Carmelitas mining venture in
Venezuela and the related Palmarejo export port facility on Lake
Maracaibo in Venezuela. We and the AMCI Parties each funded
$3.25 million of our respective subscription obligations in
September 2004, an additional $1.25 million in December
2004 and the remaining $500,000 in March 2005. The Las
Carmelitas mine, which is not yet in operation, is currently
expected to produce approximately two million tons of low sulfur
thermal coal per year over a
15-year mine life. The
project is currently in the developmental stage, with
preliminary governmental mining and environmental approvals
having been obtained. Final governmental approval of the
project, which is subject to the submission of a detailed mine
plan, is currently expected in 2006 with mining to commence in
2007.
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Distributions to Members of ANR Holdings and Our
Stockholders
From its formation in December 2002 through the date of our
Internal Restructuring, ANR Holdings made periodic distributions
to its members, including First Reserve, entities affiliated
with AMCI, and Alpha Coal Management, on dates and in amounts
calculated in accordance with its governing documents,
sufficient to enable the members to pay their estimated income
tax liability associated with their ownership of ANR Holdings.
The amounts of these distributions by ANR Holdings, which were
funded by cash distributions made to ANR Holdings by Alpha
Natural Resources, LLC, totaled $5.3 million and
$14.0 million during 2003 and 2004, respectively, and
$1.1 million during the period from January 1, 2005
through the date of our Internal Restructuring.
On May 28, 2004, in connection with the closing under our
credit agreement and our receipt of the proceeds from the sale
of the notes, Alpha Natural Resources, LLC distributed
$110.0 million to ANR Holdings, which in turn distributed
an aggregate of $110.0 million to its members, including
First Reserve, entities affiliated with AMCI, and Alpha Coal
Management, in proportion to their common sharing ratios in ANR
Holdings.
In connection with the Internal Restructuring, we assumed the
obligation of ANR Holdings to make the Tax Distributions to
(1) affiliates of AMCI in an aggregate amount of
$6.0 million, representing the approximate incremental tax
resulting from the recognition of additional tax liability
resulting from the Internal Restructuring and (2) First
Reserve Fund IX, L.P. in an aggregate amount of
approximately $4.5 million, representing the approximate
value of tax attributes conveyed as a result of the Internal
Restructuring. The Tax Distributions to affiliates of AMCI will
be paid in five equal installments on the dates for which
estimated income tax payments are due in each of April 2005,
June 2005, September 2005, January 2006 and April 2006. The
first three of these payments were made on April 15, 2005,
June 15, 2005 and September 15, 2005 in the amount of
$1.2 million each in cash. The Tax Distributions to First
Reserve Fund IX, L.P. will be paid in three installments of
approximately $2.1 million, $2.1 million and
$0.3 million on December 15, 2007, 2008 and 2009,
respectively. The Tax Distributions will be payable in cash to
the extent we are permitted by the terms of the indenture
governing the notes and our credit facility to distribute the
required funds to us or, if we are not permitted to make such
cash distributions, the Tax Distributions will be payable in
shares of our common stock.
Alpha Natural Resources, LLC distributed an aggregate of
$5.3 million and $123.9 million to ANR Holdings during
2003 and 2004.
Transactions in Connection with Internal Restructuring
On February 11, 2005, we and ANR Holdings completed a
series of transactions in connection with the Internal
Restructuring which involved transactions with the First Reserve
Stockholders and the AMCI Parties and certain of our managers
and key employees. These transactions included the following:
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Amendment to AMCI Related Agreements: We amended certain
of the post-closing arrangements that are part of our
acquisition of U.S. AMCI discussed above. The AMCI Parties
posted for our benefit a letter of credit that provides, for a
period of ten years, financial assurances supporting the
obligations of the AMCI Parties to indemnify us under the
contribution agreement in respect of certain retiree medical
liabilities. The letter of credit is initially in the amount of
$6.8 million, declining to $3.8 million in the sixth
and seventh years, and further declining to $1.8 million in
the eighth through tenth years. The escrow and pledge agreements
with the AMCI Parties and all of the First Reserve purchase
right arrangements described in Transactions
in Connection with the U.S. AMCI Acquisition were
terminated. |
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Releases and Indemnities. Each former member of ANR
Holdings (including members of our management team) released us
and our past, present and future affiliates from any and all
claims such member may have against ANR Holdings relating to
events occurring prior to the closing. We, in turn, agreed to
indemnify them with respect to any action which may be brought
against any former member by reason of the fact that the member
was a member, managing member, executive committee member or
officer of ANR Holdings prior to the closing of the Internal
Restructuring, other than with respect to any acts committed in
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active and deliberate dishonesty or from which the member gained
financial profit or another advantage to which the member was
not legally entitled. |
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Additionally, First Reserve Fund IX, L.P. agreed to
indemnify us against certain pre-closing liabilities, including
tax liabilities, associated with Alpha NR Holding, Inc. in an
amount not to exceed $15.0 million for the first two years
following consummation of the agreement, at which time the
amount for which First Reserve Fund IX, L.P. will be
obligated to indemnify will decline to $10.0 million for
two additional years. |
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Stockholder Agreement. We entered into a stockholder
agreement with our management stockholders, the First Reserve
Stockholders, the AMCI Parties and Madison Capital Funding LLC
that became effective upon consummation of the Internal
Restructuring and replaced the former member agreement among
these parties and ANR Holdings. As part of the stockholder
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Agreement on Board Composition: Our board of directors
consisted of seven members upon consummation of our initial
public offering. The board may be subsequently expanded to
include additional independent directors as may be required by
the rules of any exchange on which shares of our common stock
are traded. Each of the First Reserve Stockholders and the AMCI
Parties will designate two nominees for
election (initially, Messrs. Macaulay and Krueger, as
to the First Reserve Stockholders, and Messrs. Kundrun and
Mende as to the AMCI Parties). Our board of directors will
designate as directors our chief executive officer
(Mr. Quillen) and two other nominees who must be
independent as that term is defined by the NYSE
rules (initially Messrs. Draper and Fox), but the
independent nominees must be reasonably acceptable to both the
First Reserve Stockholders and the AMCI Parties. If at any time,
either the First Reserve Stockholders or the AMCI Parties and
their affiliates as a group beneficially own less than 15% of
our outstanding shares of common stock, then the applicable
party will only be entitled to designate one director, and if
either the First Reserve Stockholders or the AMCI Parties and
their affiliates as a group beneficially own less than 7.5% of
our outstanding shares of common stock, then the applicable
party will no longer be entitled to designate any directors
pursuant to the stockholder agreement. If either of the First
Reserve Stockholders or the AMCI Parties lose the right to
designate one or both of their director designees due to a
reduction in their percentage holdings of our outstanding shares
of common stock below the applicable thresholds described in the
preceding sentence, then the applicable party is obligated to
cause the resignation or removal of their director designee or
designees, as applicable, upon our request; and |
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Registration Rights: Each of the First Reserve
Stockholders and the AMCI Parties have the right in certain
circumstances to require us to register their shares of common
stock in connection with a public offering and sale. In
addition, in connection with other registered offerings by us,
existing holders of shares of its common stock will have the
ability to exercise certain piggyback registration rights with
respect to the shares. The registration statement of which this
prospectus forms a part was filed by us pursuant to an exercise
by the First Reserve Stockholders of their demand registration
rights and includes the registration of the offer and sale of
shares by Madison Capital Funding LLC pursuant to an exercise of
their piggyback registration rights. |
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DESCRIPTION OF INDEBTEDNESS
Credit Facility
In connection with the Nicewonder Acquisition, Alpha Natural
Resources, LLC and Alpha NR Holding, Inc. entered into a senior
secured credit facility with Citicorp North America, Inc, as
administrative agent and collateral agent, Citigroup Global
Markets Inc., as joint lead arranger and joint book manager, UBS
Securities LLC, as syndication agent, joint lead arranger and
joint book manager, Bank of America, N.A., National City Bank of
Pennsylvania and PNC Bank, National Association, as
co-documentation agents, and each lender party thereto.
The new senior secured credit facility provides senior secured
financing of $525.0 million, consisting of
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a $250.0 million term loan facility; and |
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a $275.0 million revolving credit facility. |
The term loan was fully drawn upon consummation of the
Nicewonder Acquisition. The proceeds from the term loan and a
portion of the revolving credit facility were used to refinance
the prior credit facility and to pay the cash purchase price,
related fees and expenses and the first installment payment due
on the installment promissory notes issued to the sellers
pursuant to the Nicewonder Acquisition. As of September 30,
2005, on a pro forma basis, we would have had approximately
$55.3 million of indebtedness outstanding,
$65.5 million of letters of credit outstanding and
additional borrowings available under the revolving credit
facility of $154.2 million.
Upon the occurrence of certain events, Alpha Natural Resources,
LLC may request an increase to the existing term loan facility
and/or the existing revolving credit facility in an amount not
to exceed $100.0 million, subject to receipt of commitments
by existing lenders or other financial institutions reasonably
acceptable to the administrative agent.
Alpha Natural Resources, LLC is the borrower under the term loan
facility and the revolving credit facility. The revolving credit
facility includes borrowing capacity available for
$275.0 million of letters of credit and for borrowings on
same-day notice, referred to as the swingline loans.
The borrowings under the senior secured credit facility bear
interest at a rate equal to an applicable margin plus, at our
option, either (a) a base rate determined by reference to
the highest of (1) the base rate of Citibank, N.A.,
(2) the three-month certificate of deposit rate, plus
1/2
of 1%, and (3) the federal funds rate plus
1/2
of 1% or (b) the current LIBO rate as quoted by the
administrative agent, adjusted for reserve requirements, if any,
and subject to customary change of circumstance provisions, for
interest periods of one, two, three or six months. The initial
applicable margin for borrowings under the term loan facility is
0.75% with respect to base rate borrowings and 1.75% with
respect to LIBOR borrowings. The initial applicable margin for
borrowings under the revolving credit facility is 1.00% with
respect to base rate loans and 2.00% with respect to LIBOR
borrowings. The applicable margin for borrowings under the term
loan facility may be reduced, and the applicable margin for
borrowings under the revolving credit facility may be increased
or reduced, in each case, subject to our attaining certain
leverage ratios.
In addition to paying interest on outstanding principal under
the senior secured credit facility, Alpha Natural Resources, LLC
is required to pay a commitment fee to the lenders under the
revolving credit facility in respect of the unutilized
commitments thereunder. The initial commitment fee rate is
0.50% per annum. The commitment fee rate may be reduced
subject to Alpha NR Holding, Inc. attaining certain leverage
ratios. Alpha Natural Resources, LLC will also pay customary
letter of credit fees.
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The senior secured credit facility requires Alpha Natural
Resources, LLC to prepay outstanding term loans, subject to
certain exceptions, with:
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100% of the net cash proceeds from any issuance or incurrence of
debt by Alpha NR Holding, Inc. or its subsidiaries, other than
certain debt permitted under the senior secured credit
facility; and |
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100% of the net cash proceeds in excess of $5.0 million in
a single transaction or $10.0 million per fiscal year from
asset sales and condemnation events, subject to certain
exceptions, including in the case of asset sales resulting in
net proceeds of $50.0 million or less, our ability to
reinvest those proceeds in assets to be used in our business or
to make certain other permitted investments within
12 months. |
The foregoing mandatory prepayments will be applied to the
remaining installments of the term loan facility on a
pro rata basis.
Alpha Natural Resources, LLC may voluntarily repay outstanding
loans under the senior secured credit facility at any time
without premium or penalty, other than customary
breakage costs with respect to LIBOR loans.
Alpha Natural Resources, LLC is required to repay installments
on the loans under the term loan facility in quarterly principal
amounts of $625,000 commencing March 31, 2006, with the
remaining amount payable on October 26, 2012.
Principal amounts outstanding under the revolving credit
facility will be due and payable in full on October 26,
2010.
All obligations under the senior secured credit facility are
unconditionally guaranteed by Alpha NR Holding, Inc. and each of
its existing and future direct and indirect domestic
subsidiaries (other than Alpha Natural Resources, LLC, the
borrower), referred to, collectively, as Guarantors.
All obligations under the senior secured credit facility, and
the guarantees of those obligations, are secured by
substantially all the assets of Alpha Natural Resources, LLC and
each Guarantor, including, but not limited to, the following,
and subject to certain exceptions:
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a pledge of (i) all notes having an aggregate principal
amount in excess of $10.0 million owned by Alpha Natural
Resources, LLC and the Guarantors and (ii) 100% of the
capital stock (or other ownership interests) owned by Alpha
Natural Resources, LLC and the Guarantors (but not more than 66%
of the voting stock of each foreign subsidiary of Alpha Natural
Resources, LLC and the Guarantors), subject to certain
exceptions; and |
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a security interest in substantially all the tangible and
intangible personal property and all material real property of
Alpha Natural Resources, LLC and each Guarantor. |
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Certain Covenants and Events of Default |
The senior secured credit facility contains a number of
covenants that, among other things, restrict, subject to certain
exceptions, Alpha Natural Resources, LLCs ability, and the
ability of each Guarantor, to:
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sell assets; |
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incur additional indebtedness or issue preferred stock; |
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repay other indebtedness; |
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pay dividends and distributions or repurchase our capital stock; |
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create liens on assets; |
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make investments, loans or advances; |
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make certain acquisitions; |
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engage in mergers or consolidations; |
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engage in certain transactions with affiliates; |
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amend certain material agreements governing our indebtedness,
including the notes; |
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change the business conducted by Alpha NR Holding, Inc. and its
subsidiaries; and |
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enter into agreements that restrict dividends from subsidiaries. |
In addition, the senior secured credit facility requires Alpha
NR Holding, Inc. and its subsidiaries to maintain the following
financial covenants:
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a maximum total leverage ratio; |
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a minimum interest coverage ratio; and |
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a maximum capital expenditures limitation. |
The senior secured credit facility also contains certain
customary affirmative covenants and events of default.
10% Senior Notes due 2012
In May 2004, Alpha Natural Resources, LLC and its wholly owned
subsidiary Alpha Natural Resources Capital Corp. (the
Issuers) issued $175.0 million aggregate
principal amount of 10% senior notes due June 1, 2012.
The Issuers issued the senior notes in transactions exempt from
or not subject to registration under the Securities Act,
pursuant to Rule 144A and Regulation S under the
Securities Act. Interest on the senior notes accrues at the rate
of 10% per annum and is payable semi-annually on
June 1 and December 1.
The senior notes are the Issuers senior unsecured
obligations and rank equally in right of payment to all of the
Issuers existing and future senior unsecured indebtedness;
rank senior in right of payment to any future senior
subordinated indebtedness and subordinated indebtedness of the
Issuers; and are effectively subordinated in right of payment to
the Issuers secured indebtedness (including obligations
under our credit facility) to the extent of the value of the
assets securing the indebtedness, and all obligations of each of
the Issuers future subsidiaries that are not guarantors.
The Issuers obligations under the senior notes are jointly
and severally guaranteed on a senior unsecured basis by all of
Alpha Natural Resources, LLCs existing and future domestic
restricted subsidiaries (including its new and acquired
subsidiaries resulting from the Nicewonder Acquisition). In
addition, Alpha NR Holding, Inc. is a parent guarantor under the
senior notes.
The Issuers may redeem any of the senior notes at any time on or
after June 1, 2008, in whole or in part, in cash at the
redemption prices described in the indenture governing the
senior notes, plus accrued and unpaid interest to the date of
redemption. In addition, on or before June 1, 2007, the
Issuers may
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redeem up to 35% of the aggregate principal amount of senior
notes at a redemption price equal to 110% of the principal
amount of senior notes with the net proceeds of certain
underwritten equity offerings. The Issuers may make that
redemption only if it occurs within 180 days of the
consummation of the underwritten equity offering and if, after
the redemption, at least 65% of the aggregate principal amount
of senior notes remains outstanding. The Issuers may
redeem any of the senior notes at any time before June 1,
2008 in cash at 100% of the principal amount plus accrued and
unpaid interest to the date of redemption and a make-whole
premium.
Upon a change of control, the Issuers may be required to make an
offer to purchase each holders senior notes at a price
equal to 101% of the principal amount thereof, plus accrued and
unpaid interest, if any, to the date of purchase.
The indenture governing the senior notes contains covenants
that, among other things, limit the ability of the Issuers and
their restricted subsidiaries to:
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incur additional indebtedness; |
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pay dividends on or make other distributions or repurchase the
capital stock of the Issuers or their restricted subsidiaries; |
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make certain investments; |
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enter into certain types of transactions with affiliates; |
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create or permit to exist any limit on the ability of the
Issuers restricted subsidiaries to pay dividends or make
other payments to the Issuers or their restricted subsidiaries,
other than pursuant to the credit facility and the senior notes
indenture; |
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use assets as security in other transactions; and |
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These limitations are subject to a number of important
qualifications and exceptions as described in the indenture
governing the senior notes.
The indenture governing the senior notes also provides for
events of default which, if any of them occurs, would permit or
require the principal of and accrued interest on the senior
notes to become or to be declared due and payable. As of
September 30, 2005, we were in compliance in all material
respects with all covenants and provisions contained under the
indenture governing the senior notes.
Installment Promissory Notes
In connection with the Nicewonder Acquisition, our subsidiary,
Callaway Natural Resources, Inc., issued $221.0 million
principal amount of unsecured installment promissory notes to
the sellers of the Nicewonder Coal Group. The promissory notes
are payable in two installments, of which $181.1 million
was paid on November 2, 2005 and the remaining
$39.9 million is due on January 15, 2006. The
promissory notes bear interest at the rate of 3.82% per annum.
The promissory notes may be prepaid at any time without premium
or penalty. The promissory notes contain customary events of
default upon failure to pay principal or interest on the notes
and bankruptcy or insolvency of the issuer, but do not contain
any restrictive or financial covenants.
Federal and state laws require surety bonds to secure our
obligations to reclaim lands disturbed for mining, to pay
federal and state workers compensation and to satisfy
other miscellaneous obligations. The
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amount of the reclamation bonds varies constantly, depending
upon the amount of acreage disturbed and the degree to which
each property has been reclaimed. Under federal law, partial
bond release is provided as mined lands (1) are backfilled
and graded to approximate original contour, (2) are
re-vegetated and (3) achieve pre-mining vegetative
productivity levels on a sustained basis for a period of five to
10 years.
We have a committed bonding facility with Travelers Casualty and
Surety Company of America, pursuant to which Travelers has
agreed, subject to certain conditions, to issue certain surety
bonds on behalf of us and our subsidiaries in a maximum amount
of $150.0 million. The bonding facility is supported by
letters of credit in an amount up to 50% of the aggregate bond
liability. As of September 30, 2005, we have posted an
aggregate of $88.9 million in reclamation bonds and
$8.6 million of other types of bonds under this facility.
On a pro forma basis giving effect to the Nicewonder
Acquisition, we would have posted an aggregate of
$112.6 million in reclamation bonds under this facility as
of September 30, 2005.
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DESCRIPTION OF CAPITAL STOCK
The following is a description of the material terms of our
restated certificate of incorporation and amended and restated
bylaws as each is in effect as of the date of this prospectus.
We refer you to our restated certificate of incorporation and
amended and restated bylaws, copies of which have been filed as
exhibits to the registration statement relating to our IPO.
Authorized Capitalization
Our authorized capital stock consists of
(1) 100,000,000 shares of common stock, par value
$0.01 per share, of which 64,420,414 shares were
issued and outstanding as of January 1, 2006, and
(2) 10,000,000 shares of preferred stock, par value
$0.01 per share, of which no shares are currently issued
and outstanding. This offering will not change the number of
outstanding shares of our common stock.
Common Stock
Holders. As of January 1, 2006, there were
approximately 46 holders of record of our common stock.
Voting Rights. Holders of common stock are entitled to
one vote per share on all matters to be voted upon by the
stockholders. The holders of common stock do not have cumulative
voting rights in the election of directors.
Dividend Rights. Subject to applicable law and rights, if
any, of the holders of any outstanding series of preferred stock
or any class or series of stock having a preference over the
common stock with respect to the payment of dividends, dividends
may be declared and paid on the common stock from time to time
and in amounts as our board of directors may determine. Our
credit facility and the indenture governing our senior notes
impose restrictions on our ability to declare dividends with
respect to our common stock.
Liquidation Rights. Upon any dissolution, liquidation or
winding up, subject to any rights of any outstanding series of
preferred stock or any class or series of stock having a
preference over the common stock with respect to the
distribution of assets, our remaining assets and funds will be
distributed ratably to the holders of common stock.
Other Matters. The common stock has no preemptive or
conversion rights and is not subject to further calls or
assessment by us. There are no redemption or sinking fund
provisions applicable to the common stock. All outstanding
shares of our common stock, including the common stock offered
in this offering, are fully paid and non-assessable.
Preferred Stock
Our restated certificate of incorporation authorizes our board
of directors to establish one or more series of preferred stock
and to determine, with respect to any series of preferred stock,
the terms and rights of that series, including:
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the designation of the series; |
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the number of shares of the series, which our board may, except
where otherwise provided in the preferred stock designation,
increase or decrease, but not below the number of shares then
outstanding; |
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whether dividends, if any, will be cumulative or non-cumulative
and the dividend rate of the series; |
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the dates at which dividends, if any, will be payable; |
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the redemption rights and price or prices, if any, for shares of
the series; |
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the terms and amounts of any sinking fund provided for the
purchase or redemption of shares of the series; |
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the amounts payable on shares of the series in the event of any
voluntary or involuntary liquidation, dissolution or winding-up
of the affairs of our company; |
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whether the shares of the series will be convertible into shares
of any other class or series, or any other security, of our
company or any other corporation, and, if so, the specification
of the other class or series or other security, the conversion
price or prices or rate or rates, any rate adjustments, the date
or dates as of which the shares will be convertible and all
other terms and conditions upon which the conversion may be made; |
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on the issuance of shares of the same series or of any other
class or series; and |
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the voting rights, if any, of the holders of the series. |
Anti-takeover Effects of Certain Provisions of Our Amended
and Restated Certificate of Incorporation and Bylaws
Certain provisions of our restated certificate of incorporation
and amended and restated bylaws, which are summarized in the
following paragraphs, may have an anti-takeover effect and may
delay, defer or prevent a tender offer or takeover attempt that
a stockholder might consider in its best interest, including
those attempts that might result in a premium over the market
price for the shares held by stockholders.
Removal of Directors; Vacancies
Our amended and restated bylaws provide that directors may be
removed with or without cause upon the affirmative vote of
holders of at least a majority of the shares of stock entitled
to vote generally in the election of directors, voting together
as a single class. In addition, our amended and restated bylaws
also provide that except as otherwise provided in the
stockholders agreement, any vacancies on our board of directors
and newly created directorships will be filled only by the
affirmative vote of a majority of the remaining directors,
although less than a quorum.
No Cumulative Voting
The DGCL provides that stockholders are not entitled to the
right to cumulate votes in the election of directors unless our
restated certificate of incorporation provides otherwise. Our
restated certificate of incorporation prohibits cumulative
voting.
Calling of Special Meetings of Stockholders
Our amended and restated bylaws provide that special meetings of
our stockholders may be called only by the chairman of our
board, our President or by resolution of our board of directors
and shall be called by our President or Secretary upon the
written request of at least 10% in interest of the stockholders
entitled to vote at the meeting.
Stockholder Action by Written Consent
Our amended and restated bylaws permit stockholder action by
written consent.
Advance Notice Requirements for Stockholder Proposals and
Director Nominations
Our amended and restated bylaws provide that stockholders
seeking to nominate candidates for election as directors or to
bring business before an annual meeting of stockholders must
provide timely notice of their proposal in writing to the
corporate secretary.
Generally, to be timely, a stockholders notice must be
received at our principal executive offices not less than
90 days nor more than 120 days prior to the first
anniversary date of the date on which the company first mailed
its proxy materials for the previous years annual meeting.
Our amended and restated bylaws also specify requirements as to
the form and content of a stockholders notice. These
provisions
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may impede stockholders ability to bring matters before an
annual meeting of stockholders or make nominations for directors
at an annual meeting of stockholders.
Amendments to Our Amended and Restated Bylaws
Our restated certificate of incorporation grants our board of
directors the authority to amend and repeal our bylaws without a
stockholder vote in any manner not inconsistent with the laws of
the State of Delaware.
Limitations on Liability and Indemnification of Officers and
Directors
The DGCL authorizes corporations to limit or eliminate the
personal liability of directors to corporations and their
stockholders for monetary damages for breaches of
directors fiduciary duties. Our restated certificate of
incorporation includes a provision that eliminates the personal
liability of directors for monetary damages for actions taken as
a director, except for liability:
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for breach of duty of loyalty; |
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for acts or omissions not in good faith or involving intentional
misconduct or knowing violation of law; |
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under Section 174 of the DGCL (unlawful dividends); or |
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transactions from which the director derived improper personal
benefit. |
Our restated certificate of incorporation and amended and
restated bylaws provide that we must indemnify our directors and
officers to the fullest extent authorized by the DGCL. We are
also expressly authorized to carry directors and
officers insurance providing indemnification for our
directors, officers, employees and agents for some liabilities.
We believe that these indemnification provisions and insurance
are useful to attract and retain qualified directors and
executive officers.
The limitation of liability and indemnification provisions in
our restated certificate of incorporation and amended and
restated bylaws may discourage stockholders from bringing a
lawsuit against directors for breach of their fiduciary duty.
These provisions may also have the effect of reducing the
likelihood of derivative litigation against directors and
officers, even though a derivative action, if successful, might
otherwise benefit us and our stockholders. In addition, your
investment may be adversely affected to the extent we pay the
costs of settlement and damage awards against directors and
officers pursuant to these indemnification provisions.
There is currently no pending material litigation or proceeding
involving any of our directors, officers, employees or agents
for which indemnification is sought.
Corporate Opportunities
Our restated certificate of incorporation will provide for the
allocation of certain corporate opportunities between us, on the
one hand, and the First Reserve Stockholders, the AMCI Parties,
and their affiliates, on the other hand. Specifically:
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None of the First Reserve Stockholders, the AMCI Parties, or the
funds or other entities controlled by, or under common control
with, them (each a Control Stockholder, and
collectively, the Control Stockholders) or any
director, officer, member, partner, stockholder or employee of a
Control Stockholder (each a Specified Party) will
have any duty to refrain from engaging directly or indirectly in
the same or similar business activities or lines of business as
we do. |
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Except as noted below, we renounce any interest or expectancy
that we may have in any potential transaction which may be a
corporate opportunity for any Control Stockholder or Specified
Party, as applicable, on the one hand, and us, on the other
hand, and therefore, none of the Control Stockholders or
Specified Parties will have any duty to communicate or offer any
such corporate opportunity to us, and will be entitled to pursue
or acquire such opportunity for itself, and we will |
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have no right in or to any such opportunity. Notwithstanding the
prior sentence, we are not renouncing any interest or expectancy
in any such corporate opportunity that is offered to any Control
Stockholder or Specified Party that is also one of our
directors, officers, or employees, if (i) such opportunity
is expressly offered to such Control Stockholder or Specified
Party solely in, and as a direct result of, his or her capacity
as our director, officer or employee; (ii) we would be
permitted to undertake the opportunity under our amended and
restated certificate of incorporation, and (iii) we have
sufficient financial resources and are in a line of business to
undertake the opportunity. |
Delaware Anti-Takeover Statute
We have opted out of Section 203 of the DGCL. Subject to
specified exceptions, Section 203 prohibits a publicly held
Delaware corporation from engaging in a business
combination with an interested stockholder for
a period of three years after the date of the transaction in
which the person became an interested stockholder.
Business combinations include mergers, asset sales
and other transactions resulting in a financial benefit to the
interested stockholder. Subject to various
exceptions, an interested stockholder is a person
who together with his or her affiliates and associates, owns, or
within three years did own, 15% or more of the
corporations outstanding voting stock. These restrictions
generally prohibit or delay the accomplishment of mergers or
other takeover or change-in-control attempts.
Transfer Agent and Registrar
EquiServe Trust Company, N.A. is the transfer agent and
registrar for our common stock.
Listing
Our common stock trades on the New York Stock Exchange under the
symbol ANR.
Authorized but Unissued Capital Stock
The DGCL does not require stockholder approval for any issuance
of authorized shares. However, the listing requirements of the
New York Stock Exchange, which would apply so long as our common
stock is listed on the New York Stock Exchange, require
stockholder approval of certain issuances equal to or exceeding
20% of the then-outstanding voting power or then outstanding
number of shares of common stock. These additional shares may be
used for a variety of corporate purposes, including future
public offerings, to raise additional capital or to facilitate
acquisitions.
One of the effects of the existence of unissued and unreserved
common stock may be to enable our board of directors to issue
shares to persons friendly to current management, which issuance
could render more difficult or discourage an attempt to obtain
control of our company by means of a merger, tender offer, proxy
contest or otherwise, and thereby protect the continuity of our
management and possibly deprive the stockholders of
opportunities to sell their shares of common stock at prices
higher than prevailing market prices.
143
SHARES ELIGIBLE FOR FUTURE SALE
We cannot predict what effect, if any, market sales of shares of
common stock or the availability of shares of common stock for
sale will have on the market price of our common stock.
Nevertheless, sales of substantial amounts of common stock in
the public market, or the perception that such sales could
occur, could materially and adversely affect the market price of
our common stock and could impair our future ability to raise
capital through the sale of our equity or equity-related
securities at a time and price that we deem appropriate.
As of January 1, 2006, we had outstanding
64,420,414 shares of our common stock. Of the outstanding
shares, the shares sold in this offering and in our IPO, as well
as shares that have been resold since the IPO pursuant to
Rule 144 or Rule 701 or issued by us pursuant to our
registration statement on
Form S-8, are
freely tradeable without restriction or further registration
under the Securities Act, except that any shares held by our
affiliates, as that term is defined under
Rule 144 of the Securities Act, may be sold only in
compliance with the limitations described below. The remaining
outstanding shares of common stock were issued and sold by us in
private transactions and have not been resold pursuant to
Rule 144 or Rule 701 and are therefore
restricted securities as that term is defined under
Rule 144. These remaining shares are eligible for public
sale if registered under the Securities Act or sold in
accordance with Rule 144 or Rule 701 under the
Securities Act, which are summarized below. As a result of the
provisions of Rule 144 and 701 and assuming the
underwriters option is exercised in full, 13,147,040 of
the restricted securities will be eligible for sale in the
public market following the expiration of the
90-day lock-period
described below under
Lock-Up
Agreements (in all cases subject to the requirement that
no unvested shares may be sold before they vest).
Rule 144
In general, under Rule 144 as currently in effect, a person
(or persons whose shares are required to be aggregated),
including an affiliate, who has beneficially owned
restricted securities for at least one year is
entitled to sell in any three-month period a number of shares
that does not exceed the greater of:
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1% of the number of shares of common stock then outstanding,
which equals approximately 644,204 shares based on the
number of outstanding shares as of January 1, 2006; and |
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the average weekly reported volume of trading in the common
stock on the New York Stock Exchange during the four calendar
weeks preceding the date on which notice of sale is filed,
subject to restrictions. |
Sales under Rule 144 are also subject to manner of sale
provisions and notice requirements and to the availability of
current public information about us. Rule 144 also provides
that our affiliates who sell shares of our common stock that are
not restricted shares must nonetheless comply with the same
restrictions applicable to restricted shares with the exception
of the holding period requirement.
Rule 144(k)
Under Rule 144(k), a person who is not deemed to have been
one of our affiliates for purposes of the Securities Act at any
time during the 90 days preceding a sale and who has
beneficially owned the shares proposed to be sold for at least
two years, including the holding period of any prior owner other
than our affiliates, would be entitled to sell those shares
without complying with the manner of sale, public information,
volume limitation or notice requirements of Rule 144.
Rule 701
In general, under Rule 701 as currently in effect, any of
our employees who acquired shares from us in connection with a
compensatory stock or option plan or other written agreement,
including pursuant to the Internal Restructuring, in a
transaction that was completed in reliance on Rule 701 and
complied with the requirements of Rule 701 is now eligible
to resell such shares in reliance on Rule 144, but without
compliance with certain restrictions, including the holding
period, contained in Rule 144.
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Lock-Up Agreements
We, each of the selling stockholders and our directors and
executive officers have agreed with the underwriters not to
sell, dispose of or hedge any of their common stock or
securities convertible into or exchangeable for shares of common
stock during the period from the date of this prospectus
continuing through the date 90 days after the date of this
prospectus, except with the prior written consent of Morgan
Stanley & Co. Incorporated, Citigroup Global Markets
Inc. and UBS Securities LLC.
The restrictions described in the previous paragraph do not
apply to:
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the sale of shares of common stock to the underwriters pursuant
to this offering; |
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the issuance by us of shares of common stock pursuant to the
exercise of an option, warrant or similar security outstanding
on the date of this prospectus; |
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the grant of options or stock under our benefit plans; |
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transactions by any person other than us relating to shares of
our common stock acquired in open market transactions after
completion of this offering; |
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transfers of shares of common stock, or securities convertible
into or exercisable or exchangeable for shares of common stock,
as a bona fide gift or as a result of testate, intestate
succession or bona fide estate planning; transfers of shares to
a trust, partnership, limited liability company or other entity,
all of the beneficial ownership interests of which are held by
the transferor; or distributions of shares to limited partners,
members or stockholders of the transferor, in each case provided
that the transferee or distributee (other than any charitable
organization) agrees to be bound by the restrictions described
in the previous paragraph; |
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the issuance of common stock or securities convertible into or
exercisable or redeemable for shares of common stock in
connection with the acquisition of, or joint venture with,
another company; or |
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the entry into trading plans providing for trades after the
expiration of the lock-up period by certain of our executive
officers in accordance with
Rule 10b5-1 under
the Securities Act of 1934, or the execution of trades by
certain of our executive officers under their existing trading
plans. |
Certain of our executive officers have advised us that they
intend to sell shares of our common stock over a period of time,
subject to the foregoing restrictions. We anticipate that these
sales will be effected under existing or new trading plans in
accordance with Rule 10b5-1 under the Securities Exchange
Act of 1934.
Registration Rights
The stockholder agreement provides that both the First Reserve
Stockholders and the AMCI Parties each have the right to require
us to register their shares of common stock in connection with a
public offering and sale, which right will terminate with
respect to either stockholder group when that group holds less
than 10% of the registrable shares (as defined in the
stockholder agreement). In addition, in connection with other
registered offerings by us, holders of shares of our common
stock issued in the Internal Restructuring and in connection
with the Nicewonder Acquisition will have the ability to
exercise certain piggyback registration rights. Pursuant to the
lock-up agreements described above, the selling stockholders
have agreed not to make any demand for registration of their
shares of common stock during the period ending 90 days after
the date of this prospectus without the prior written consent of
Morgan Stanley & Co. Incorporated, Citigroup Global
Markets Inc. and UBS Securities LLC, except that the AMCI
Parties may issue to the Company a registration demand pursuant
to the stockholder agreement so long as no registration
statement is filed during the 90-day period.
145
Stock Options
Pursuant to the Alpha Coal Management Long-Term Incentive Plan,
there are outstanding as of January 1, 2006 options to
purchase an aggregate of 510,688 shares of common stock,
which options vest at 20% per annum over a period of five
years beginning November 10, 2004, with the first 20%
having vested on November 10, 2005. Pursuant to our
Long-Term Incentive Plan, there are outstanding as of
January 1, 2006 options to purchase an aggregate of
742,905 shares of common stock, which also vest at
20% per annum over five-year periods. We filed a
registration statement on
Form S-8 under the
Securities Act to register all shares of common stock subject to
outstanding options and otherwise reserved for issuance under
the Alpha Coal Management Long-Term Incentive Plan and the
Long-Term Incentive Plan. After expiration of the applicable
contractual resale restrictions, shares covered by this
registration statement will be eligible for sale in the public
market, other than shares owned by our affiliates, which may be
sold in the public market only if they are registered or qualify
for an exemption from registration under Rule 144.
146
MATERIAL U.S. FEDERAL INCOME AND ESTATE TAX
CONSEQUENCES
TO NON-U.S. HOLDERS
The following is a summary of certain United States federal
income and estate tax consequences of the purchase, ownership
and disposition of our common stock as of the date of this
prospectus. Except where noted, this summary deals only with
common stock that is held as a capital asset by a
non-U.S. holder. A non-U.S. holder means a
person (other than a partnership) that is not for United States
federal income tax purposes any of the following:
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an individual citizen or resident of the United States including
an alien individual who is a lawful permanent resident of the
United States or meets the substantial presence test
under Section 7701(b) of the Code; |
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a corporation (or any other entity treated as a corporation for
United States federal income tax purposes) created or organized
in or under the laws of the United States, any state thereof or
the District of Columbia; |
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an estate the income of which is subject to United States
federal income taxation regardless of its source; or |
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a trust if it (1) is subject to the primary supervision of
a court within the United States and one or more United States
persons have the authority to control all substantial decisions
of the trust or (2) has a valid election in effect under
applicable United States Treasury regulations to be treated as a
United States person. |
This summary is based upon provisions of the Internal Revenue
Code of 1986, as amended (the Code), and
regulations, rulings and judicial decisions as of the date
hereof. Those authorities may be changed, perhaps retroactively,
so as to result in United States federal income and estate tax
consequences different from those summarized below. This summary
does not address all aspects of United States federal income and
estate taxes and does not deal with foreign, state, local or
other tax considerations that may be relevant to
non-U.S. holders in light of their personal circumstances.
In addition, it does not represent a detailed description of the
United States federal income and estate tax consequences
applicable to you if you are subject to special treatment under
the United States federal income tax laws (including if you are
a United States expatriate, controlled foreign
corporation, passive foreign investment
company, or corporation that accumulates earnings to avoid
United States federal income tax). A change in law may alter
significantly the tax considerations that we describe in this
summary.
If a partnership holds our common stock, the tax treatment of a
partner will generally depend upon the status of the partner and
the activities of the partnership. If you are a partner of a
partnership holding our common stock, you should consult your
tax advisors.
If you are considering the purchase of our common stock, we
recommend that you consult your own tax advisors concerning the
particular United States federal income and estate tax
consequences to you of the ownership of the common stock, as
well as the consequences to you arising under the laws of any
other taxing jurisdiction.
Dividends
In the event that we pay dividends, dividends paid to a
non-U.S. holder of our common stock generally will be
subject to withholding of United States federal income tax at a
30% rate or such lower rate as may be specified by an applicable
income tax treaty. However, dividends that are effectively
connected with the conduct of a trade or business by the
non-U.S. holder within the United States (and, where a tax
treaty applies, are attributable to a United States permanent
establishment of the non-U.S. holder) are not subject to
the withholding tax, provided certain certification and
disclosure requirements are satisfied. Instead, such dividends
are subject to United States federal income tax on a net income
basis in the same manner as if the non-U.S. holder were a
United States person as defined under the Code. Any such
effectively connected dividends received by a foreign
corporation may be subject to an additional branch profits
tax at a 30% rate or such lower rate as may be specified
by an applicable income tax treaty.
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A non-U.S. holder of our common stock who wishes to claim
the benefit of an applicable treaty rate and avoid backup
withholding, as discussed below, for dividends will be required
to (a) complete Internal Revenue Service Form W-8BEN
(or other applicable form) and certify under penalty of perjury
that such holder is not a United States person as defined under
the Code or (b) if our common stock is held through certain
foreign intermediaries, satisfy the relevant certification
requirements of applicable United States Treasury regulations.
Special certification and other requirements apply to certain
non-U.S. holders that are entities rather than individuals.
A non-U.S. holder of our common stock eligible for a
reduced rate of United States withholding tax pursuant to an
income tax treaty may obtain a refund of any excess amounts
withheld by filing an appropriate claim for refund with the
Internal Revenue Service.
Gain on Disposition of Common Stock
Any gain realized on the disposition of our common stock
generally will not be subject to United States federal income
tax unless:
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the gain is effectively connected with a trade or business of
the non-U.S. holder in the United States, and, if required
by an applicable income tax treaty, is attributable to a United
States permanent establishment of the non-U.S. holder; |
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the non-U.S. holder is an individual who is present in the
United States for 183 days or more in the taxable year of
that disposition, and certain other conditions are met; or |
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we are or have been a United States real property holding
corporation for United States federal income tax purposes. |
An individual non-U.S. holder described in the first bullet
point immediately above will be subject to tax on the net gain
derived from the sale under regular graduated United States
federal income tax rates. An individual non-U.S. holder
described in the second bullet point immediately above will be
subject to a flat 30% tax on the gain derived from the sale,
which may be offset by United States source capital losses, even
though the individual is not considered a resident of the United
States. If a non-U.S. holder that is a foreign corporation
falls under the first bullet point immediately above, it
generally will be subject to tax on its net gain in the same
manner as if it were a United States person as defined under the
Code and, in addition, may be subject to the branch profits tax
equal to 30% of its effectively connected earnings and profits
or at such lower rate as may be specified by an applicable
income tax treaty.
We believe that we are currently a United States real
property holding corporation for United States federal
income tax purposes. So long as our common stock is regularly
traded on an established securities market, only a
non-U.S. holder who holds or held (at any time during the
shorter of the five year period preceding the date of
disposition or the holders holding period) more than 5% of
our common stock will be subject to United States federal income
tax on the disposition of our common stock.
If a non-U.S. holder owned directly or indirectly more than
5% of our common stock at any time during the applicable period
or our common stock was not considered to be regularly
traded on an established securities market, then any gain
recognized by a non-U.S. holder on the sale or other
disposition of our common stock would be treated as effectively
connected with a U.S. trade or business and would be
subject to U.S. federal income tax at regular graduated
U.S. federal income tax rates and in much the same manner
as applicable to U.S. persons. In such a case, the
non-U.S. holder could also be subject to certain
withholding taxes imposed on the gross proceeds realized with
respect to the sale or other disposition of our common stock.
Federal Estate Tax
Common stock held by an individual non-U.S. holder at the
time of death will be included in such holders gross
estate for United States federal estate tax purposes, unless an
applicable estate tax treaty provides otherwise.
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Information Reporting and Backup Withholding
We must report annually to the Internal Revenue Service and to
each non-U.S. holder the amount of dividends paid to such
holder and the tax withheld with respect to such dividends,
regardless of whether withholding was required. Copies of the
information returns reporting such dividends and withholding may
also be made available to the tax authorities in the country in
which the non-U.S. holder resides under the provisions of
an applicable income tax treaty.
A non-U.S. holder will be subject to backup withholding for
dividends paid to such holder unless such holder certifies under
penalty of perjury that it is a non-U.S. holder, and the
payor does not have actual knowledge or reason to know that such
holder is a United States person as defined under the Code, or
such holder otherwise establishes an exemption.
Information reporting and, depending on the circumstances,
backup withholding will apply to the proceeds of a sale of our
common stock within the United States or conducted through
certain United States-related financial intermediaries, unless
the beneficial owner certifies under penalty of perjury that it
is a non-U.S. holder (and the payor does not have actual
knowledge or reason to know that the beneficial owner is a
United States person as defined under the Code) or such owner
otherwise establishes an exemption.
Any amounts withheld under the backup withholding rules may be
allowed as a refund or a credit against a
non-U.S. holders United States federal income tax
liability provided the required information is furnished to the
Internal Revenue Service.
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UNDERWRITING
We, the selling stockholders and the underwriters named below
have entered into an underwriting agreement with respect to the
shares being offered. Subject to certain conditions, each
underwriter has severally agreed to purchase the number of
shares indicated in the following table. Morgan Stanley &
Co. Incorporated, Citigroup Global Markets Inc. and UBS
Securities LLC are acting as joint book-running managers and
representatives of the underwriters.
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Underwriters |
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Morgan Stanley & Co. Incorporated
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Citigroup Global Markets Inc.
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UBS Securities LLC
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Bear, Stearns & Co. Inc.
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Lehman Brothers Inc.
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Merrill Lynch, Pierce, Fenner & Smith Incorporated
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Davenport & Company LLC
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Total
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12,316,110 |
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The underwriters are committed to take and pay for all of the
shares of common stock being offered, if any are taken, other
than the shares of common stock covered by the option described
below unless and until this option is exercised.
If the underwriters sell more shares of common stock than the
total number set forth in the table above, the underwriters have
an option to buy up to an additional 1,847,417 shares of
common stock from the selling stockholders. They may exercise
that option for 30 days. If any shares of common stock are
purchased pursuant to this option, the underwriters will
severally purchase shares of common stock in approximately the
same proportion as set forth in the table above.
The following table shows the per share and total underwriting
discount to be paid to the underwriters by the selling
stockholders. Such amounts are shown assuming both no exercise
and full exercise of the underwriters over-allotment
option to purchase up to 1,847,417 additional shares of common
stock from the selling stockholders.
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Paid by Selling Stockholders |
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No Exercise | |
|
Full Exercise | |
|
|
| |
|
| |
Per Share
|
|
$ |
|
|
|
$ |
|
|
Total
|
|
$ |
|
|
|
$ |
|
|
Shares of common stock sold by the underwriters to the public
will initially be offered at the offering price set forth on the
cover of this prospectus. Any shares of common stock sold by the
underwriters to securities dealers may be sold at a discount of
up to
$ per
share from the offering price. Any such securities dealers may
resell any shares of common stock purchased from the
underwriters to certain other brokers or dealers at a discount
of up to
$ per
share from the initial public offering price. If all the shares
of common stock are not sold at the offering price, the
representatives may change the offering price and the other
selling terms.
We, our directors and executive officers and the selling
stockholders have agreed with the underwriters not to sell,
dispose of or hedge any of their common stock or securities
convertible into or exchangeable for shares of common stock,
subject to certain exceptions, during the period from the date
of this prospectus continuing through the date that is
90 days after the date of this prospectus, except with the
prior written consent of Morgan Stanley & Co.
Incorporated, Citigroup Global Markets Inc. and
UBS Securities LLC. See Shares Eligible for Future
Sale for a discussion of certain transfer restrictions and
certain exceptions to the
90-day
lock-up period.
Our common stock is listed on the New York Stock Exchange under
the symbol ANR.
150
In connection with the offering, the underwriters may purchase
and sell shares of common stock in the open market. These
transactions may include short sales, stabilizing transactions
and purchases to cover positions created by short sales. Short
sales involve the sale by the underwriters of a greater number
of shares of common stock than they are required to purchase in
the offering. Covered short sales are sales made in
an amount not greater than the underwriters option to
purchase additional shares of common stock from the selling
stockholders. The underwriters may close out any covered short
position by either exercising their option to purchase
additional shares of common stock or purchasing shares of common
stock in the open market. In determining the source of shares to
close out the covered short position, the underwriters will
consider, among other things, the price of shares available for
purchase in the open market as compared to the price at which
they may purchase additional shares of common stock pursuant to
the option granted to them. Naked short sales are
any sales in excess of such option. The underwriters must close
out any naked short position by purchasing shares of common
stock in the open market. A naked short position is more likely
to be created if the underwriters are concerned that there may
be downward pressure on the price of the common stock in the
open market after pricing that could adversely affect investors
who purchase in the offering. Stabilizing transactions consist
of various bids for or purchases of common stock made by the
underwriters in the open market prior to the completion of the
offering.
The underwriters may also impose a penalty bid. This occurs when
a particular underwriter repays to the underwriters a portion of
the underwriting discount received by it because the
representatives have repurchased shares of common stock sold by
or for the account of such underwriter in stabilizing or short
covering transactions.
Purchases to cover a short position and stabilizing transactions
may have the effect of preventing or retarding a decline in the
market price of our common stock, and together with the
imposition of the penalty bid, may stabilize, maintain or
otherwise affect the market price of the common stock. As a
result, the price of the common stock may be higher than the
price that otherwise might exist in the open market. If these
activities are commenced, they may be discontinued at any time.
These transactions may be effected on the New York Stock
Exchange, in the over-the-counter market or otherwise.
Each underwriter has represented, warranted and agreed that:
(i) it has not offered or sold and, prior to the expiry of
a period of six months from the closing of the offering, will
not offer or sell any shares of common stock to persons in the
United Kingdom except to persons whose ordinary activities
involve them in acquiring, holding, managing or disposing of
investments (as principal or agent) for the purposes of their
businesses or otherwise in circumstances which have not resulted
and will not result in an offer to the public in the United
Kingdom within the meaning of the Public Offers of Securities
Regulations 1995; (ii) it has only communicated or caused
to be communicated and will only communicate or cause to be
communicated any invitation or inducement to engage in
investment activity (within the meaning of section 21 of
the Financial Services and Markets Act 2000 (FSMA))
received by it in connection with the issue or sale of any
shares in circumstances in which section 21(1) of the FSMA
does not apply to us; and (iii) it has complied and will
comply with all applicable provisions of the FSMA with respect
to anything done by it in relation to the shares in, from or
otherwise involving the United Kingdom.
The shares may not be offered or sold, transferred or delivered,
as part of their initial distribution or at any time thereafter,
directly or indirectly, to any individual or legal entity in the
Netherlands other than to individuals or legal entities who or
which trade or invest in securities in the conduct of their
profession or trade, which includes banks, securities
intermediaries, insurance companies, pension funds, other
institutional investors and commercial enterprises which, as an
ancillary activity, regularly trade or invest in securities.
We estimate that the total expenses of the offering, excluding
underwriting discounts and commissions, will be approximately
$1.2 million.
We and the selling stockholders have agreed to indemnify the
several underwriters against certain liabilities, including
liabilities under the Securities Act of 1933 or to contribute to
payments the underwriters may be required to make because of any
of these liabilities.
151
The underwriters and their affiliates have from time to time
provided, and expect to provide in the future, investment
banking, commercial banking and other financial services to us
and our affiliates for which they have received and may continue
to receive customary fees and commissions. Morgan
Stanley & Co. Incorporated, Citigroup Global Markets
Inc., UBS Securities LLC, Bear, Stearns & Co. Inc. and
Lehman Brothers Inc. were underwriters in connection with the
initial public offering of our common stock and Morgan Stanley
& Co. Incorporated, UBS Securities LLC and Citigroup Global
Markets Inc. were initial purchasers in connection with the
offering of our subsidiaries, Alpha Natural Resources, LLC
and Alpha Natural Resources Capital Corp, 10% senior notes
due 2012. Citigroup Global Markets Inc. also acted as our
financial advisor in connection with the Nicewonder Acquisition
and Citigroup Global Markets Inc. and UBS Securities LLC acted
as joint-lead arrangers in connection with the credit facility
entered into by Alpha Natural Resources, LLC and Alpha NR
Holding, Inc. In addition, Citicorp North America, Inc., an
affiliate of Citigroup Global Markets Inc., is administrative
agent and collateral agent under the credit facility and UBS
Securities LLC is the syndication agent. Citicorp North America,
Inc. and UBS Loan Finance LLC, an affiliate of UBS
Securities LLC, are also lenders under the credit facility.
Affiliates of Morgan Stanley & Co. Incorporated and
Lehman Brothers Inc. hold less than a 1.0% and approximately a
5.6% interest, respectively, in First Reserve Fund IX,
L.P., one of the selling stockholders.
A prospectus in electronic format may be made available on the
websites maintained by one or more of the underwriters. The
representatives may agree to allocate a number of shares to
underwriters for sale to their online brokerage account holders.
The representatives will allocate shares to underwriters that
may make Internet distributions on the same basis as other
allocations. In addition, shares may be sold by the underwriters
to securities dealers who resell shares to online brokerage
account holders.
152
VALIDITY OF THE SHARES
The validity of the issuance of the shares of common stock to be
sold in this offering will be passed upon for us by Bartlit Beck
Herman Palenchar & Scott LLP, Denver, Colorado. Certain
matters of New York law will be passed upon for us by Simpson
Thacher & Bartlett LLP, New York, New York.
Latham & Watkins LLP will act as counsel to the
underwriters.
EXPERTS INDEPENDENT REGISTERED PUBLIC ACCOUNTING
FIRM
The combined financial statements of ANR Fund IX Holdings,
L.P. and Alpha NR Holding, Inc. and subsidiaries (the
Company or Successor) as of
December 31, 2004 and 2003, and for the years ended
December 31, 2004 and 2003 and the period from
December 14, 2002 to December 31, 2002 (the
Successor Periods), and for the period from
January 1, 2002 to December 13, 2002
(Predecessor Period), have been included herein and
in the registration statement in reliance upon the reports of
KPMG LLP, independent registered public accounting firm,
appearing elsewhere herein, and upon the authority of said firm
as experts in accounting and auditing. The audit report covering
the combined financial statements contains an explanatory
paragraph that states that effective December 13, 2002, the
Company acquired the majority of the Virginia coal operations of
Pittston Coal Company, a subsidiary of The Brinks Company
(formerly known as The Pittston Company), in a business
combination accounted for as a purchase. As a result of the
acquisition, the combined financial information for the period
after the acquisition is presented on a different cost basis
than that for the periods before the acquisition and, therefore,
is not comparable.
The consolidated financial statements of Coastal Coal Company,
LLC and subsidiary as of December 31, 2002, and for the
period from January 1, 2003 to January 31, 2003 and
the year ended December 31, 2002, have been included herein
and in the registration statement in reliance upon the report of
KPMG LLP, independent accountants, appearing elsewhere herein,
and upon the authority of said firm as experts in accounting and
auditing. The audit report covering the consolidated financial
statements refers to the adoption by Coastal Coal Company, LLC
and subsidiary of the provisions of FASB Statement No. 143,
Accounting for Asset Retirement Obligations, effective
January 1, 2003.
The combined financial statements of The Combined Pennsylvania
Entities of Mears Enterprises, Inc. as of December 31, 2002
and 2001, and for the period from January 1, 2003 to
November 17, 2003 and the years ended December 31,
2002 and 2001, have been included herein and in the registration
statement in reliance upon the report of KPMG LLP, independent
accountants, appearing elsewhere herein, and upon the authority
of said firm as experts in accounting and auditing. The audit
report covering the combined financial statements refers to the
adoption by The Combined Pennsylvania Entities of Mears
Enterprises, Inc. of the provisions of FASB Statement
No. 143, Accounting for Asset Retirement
Obligations, effective January 1, 2003.
The combined financial statements of The Combined Entities of
The Nicewonder Coal Group as of December 31, 2004, 2003 and
2002, and for the years then ended, have been included herein
and in the registration statement in reliance upon the report of
KPMG LLP, independent accountants, appearing elsewhere herein,
and upon the authority of said firm as experts in accounting and
auditing. The audit report covering the combined financial
statements refers to the adoption by The Combined Entities of
The Nicewonder Coal Group of the provisions of FASB Statement
No. 143, Accounting for Asset Retirement
Obligations, effective January 1, 2003.
EXPERTS COAL RESERVES
The information appearing in this prospectus concerning
estimates of the proven and probable coal reserves of the
Nicewonder Coal Group was prepared by Marshall Miller &
Associates, Inc. and has been included herein upon the authority
of this firm as an expert.
153
WHERE YOU CAN FIND ADDITIONAL INFORMATION
We have filed with the Securities and Exchange Commission (the
SEC) a registration statement on Form S-1 under
the Securities Act with respect to the issuance of shares of our
common stock being offered hereby. This prospectus, which forms
a part of the registration statement, does not contain all of
the information set forth in the registration statement. For
further information with respect to us and the shares of our
common stock, reference is made to the registration statement.
We are currently subject to the informational requirements of
the Securities Exchange Act of 1934 and, in accordance
therewith, file reports and other information with the SEC. The
registration statement, such reports and other information can
be inspected and copied at the Public Reference Room of the SEC
located at 100 F Street, N.E., Washington D.C. 20549. Copies of
such materials, including copies of all or any portion of the
registration statement, can be obtained from the Public
Reference Room of the SEC at prescribed rates. You can call the
SEC at 1-800-SEC-0330 to obtain information on the operation of
the Public Reference Room. Such materials may also be accessed
electronically by means of the SECs home page on the
Internet (http://www.sec.gov).
154
INDEX TO FINANCIAL STATEMENTS
|
|
|
|
Alpha Natural Resources, Inc. and subsidiaries
|
|
|
|
|
|
F-3 |
|
|
|
F-4 |
|
|
|
F-5 |
|
|
|
F-7 |
|
|
|
F-8 |
|
ANR Fund IX Holdings, L.P. and Alpha NR Holding, Inc.
and subsidiaries
|
|
|
|
|
|
F-25 |
|
|
|
F-26 |
|
|
|
F-27 |
|
|
|
F-28 |
|
|
|
F-29 |
|
|
|
F-31 |
|
Coastal Coal Company, LLC and subsidiary
|
|
|
|
|
|
F-75 |
|
|
|
F-76 |
|
|
|
F-77 |
|
|
|
F-78 |
|
|
|
F-79 |
|
|
|
F-80 |
|
The Combined Pennsylvania Entities of Mears Enterprises,
Inc.
|
|
|
|
|
|
F-91 |
|
|
|
F-92 |
|
|
|
F-93 |
|
|
|
F-94 |
|
|
|
F-95 |
|
|
|
F-96 |
F-1
|
|
|
|
The Combined Entities of The Nicewonder Coal
Group Unaudited Condensed Combined Financial
Statements
|
|
|
|
|
|
F-103 |
|
|
|
F-104 |
|
|
|
F-105 |
|
|
|
F-106 |
|
|
|
F-107 |
|
The Combined Entities of The Nicewonder Coal
Group Combined Financial Statements
|
|
|
|
|
|
F-114 |
|
|
|
F-115 |
|
|
|
F-116 |
|
|
|
F-117 |
|
|
|
F-118 |
|
|
|
F-119 |
F-2
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
(Unaudited) | |
|
|
(In thousands, except share | |
|
|
and per share amounts) | |
ASSETS |
Current assets:
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
111 |
|
|
$ |
7,391 |
|
|
Trade accounts receivable, net
|
|
|
151,932 |
|
|
|
95,828 |
|
|
Notes and other receivables
|
|
|
9,708 |
|
|
|
9,936 |
|
|
Inventories
|
|
|
102,856 |
|
|
|
54,569 |
|
|
Due from affiliate
|
|
|
|
|
|
|
323 |
|
|
Deferred income taxes
|
|
|
401 |
|
|
|
4,674 |
|
|
Prepaid expenses and other current assets
|
|
|
15,087 |
|
|
|
29,814 |
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
280,095 |
|
|
|
202,535 |
|
Property, plant, and equipment, net of accumulated depreciation,
depletion and amortization of $127,969 and $83,848 as of
September 30, 2005 and December 31, 2004, respectively
|
|
|
267,481 |
|
|
|
217,964 |
|
Goodwill
|
|
|
18,641 |
|
|
|
18,641 |
|
Other intangibles, net of accumulated amortization of $1,542 and
$2,343 as of September 30, 2005 and December 31, 2004,
respectively
|
|
|
560 |
|
|
|
1,155 |
|
Deferred income taxes
|
|
|
19,616 |
|
|
|
|
|
Other assets
|
|
|
35,705 |
|
|
|
36,826 |
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
622,098 |
|
|
$ |
477,121 |
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY AND PARTNERS
CAPITAL |
Current liabilities:
|
|
|
|
|
|
|
|
|
|
Current portion of long-term debt
|
|
$ |
1,046 |
|
|
$ |
1,693 |
|
|
Note payable
|
|
|
2,815 |
|
|
|
15,228 |
|
|
Bank overdraft
|
|
|
15,507 |
|
|
|
10,024 |
|
|
Trade accounts payable
|
|
|
73,208 |
|
|
|
51,050 |
|
|
Accrued expenses and other current liabilities
|
|
|
61,919 |
|
|
|
68,283 |
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
154,495 |
|
|
|
146,278 |
|
Long-term debt, net of current portion
|
|
|
257,163 |
|
|
|
184,784 |
|
Workers compensation benefits
|
|
|
5,113 |
|
|
|
4,678 |
|
Postretirement medical benefits
|
|
|
22,226 |
|
|
|
15,637 |
|
Asset retirement obligation
|
|
|
34,284 |
|
|
|
32,888 |
|
Deferred gains on sale of property interests
|
|
|
5,166 |
|
|
|
5,516 |
|
Deferred income taxes
|
|
|
|
|
|
|
7,718 |
|
Other liabilities
|
|
|
9,178 |
|
|
|
4,911 |
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
487,625 |
|
|
|
402,410 |
|
|
|
|
|
|
|
|
Minority interest
|
|
|
|
|
|
|
28,778 |
|
|
|
|
|
|
|
|
Stockholders equity and partners capital:
|
|
|
|
|
|
|
|
|
Alpha Natural Resources, Inc.:
|
|
|
|
|
|
|
|
|
|
Preferred stock par value $0.01,
10,000,000 shares authorized, none issued
|
|
|
|
|
|
|
|
|
|
Common stock par value $0.01,
100,000,000 shares authorized, 62,224,580 shares
issued and outstanding
|
|
|
622 |
|
|
|
|
|
|
Additional paid-in capital
|
|
|
146,372 |
|
|
|
|
|
|
Unearned stock-based compensation
|
|
|
(18,623 |
) |
|
|
|
|
|
Retained earnings
|
|
|
6,102 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Alpha Natural Resources, Inc. stockholders equity
|
|
|
134,473 |
|
|
|
|
|
Alpha NR Holding, Inc.:
|
|
|
|
|
|
|
|
|
|
Preferred stock par value $0.01, 1,000 shares
authorized, none issued
|
|
|
|
|
|
|
|
|
|
Common stock par value $0.01, 1,000 shares
authorized, 100 shares issued and outstanding
|
|
|
|
|
|
|
|
|
|
Additional paid-in capital
|
|
|
|
|
|
|
22,153 |
|
|
Retained earnings
|
|
|
|
|
|
|
18,828 |
|
|
|
|
|
|
|
|
|
|
Total Alpha NR Holding, Inc. stockholders equity
|
|
|
|
|
|
|
40,981 |
|
ANR Fund IX Holdings, L.P.:
|
|
|
|
|
|
|
|
|
|
Partners capital
|
|
|
|
|
|
|
4,952 |
|
|
|
|
|
|
|
|
|
|
Total stockholders equity and partners capital
|
|
|
134,473 |
|
|
|
45,933 |
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity and
partners capital
|
|
$ |
622,098 |
|
|
$ |
477,121 |
|
|
|
|
|
|
|
|
See accompanying notes to condensed consolidated financial
statements.
F-3
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
Nine Months Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(Unaudited) | |
|
|
(In thousands, except per share amounts) | |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
345,179 |
|
|
$ |
295,208 |
|
|
$ |
982,383 |
|
|
$ |
801,021 |
|
|
Freight and handling revenues
|
|
|
46,659 |
|
|
|
37,570 |
|
|
|
126,650 |
|
|
|
102,846 |
|
|
Other revenues
|
|
|
5,851 |
|
|
|
8,931 |
|
|
|
18,447 |
|
|
|
20,440 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
397,689 |
|
|
|
341,709 |
|
|
|
1,127,480 |
|
|
|
924,307 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales (exclusive of items shown separately below)
|
|
|
298,522 |
|
|
|
250,311 |
|
|
|
818,299 |
|
|
|
668,887 |
|
|
Freight and handling costs
|
|
|
46,659 |
|
|
|
37,570 |
|
|
|
126,650 |
|
|
|
102,846 |
|
|
Cost of other revenues
|
|
|
5,943 |
|
|
|
6,603 |
|
|
|
16,327 |
|
|
|
14,942 |
|
|
Depreciation, depletion and amortization
|
|
|
16,277 |
|
|
|
14,193 |
|
|
|
45,521 |
|
|
|
38,883 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above and
including stock-based compensation of $3,381 and $43,169 for the
three months and nine months ended September 30, 2005,
respectively)
|
|
|
12,147 |
|
|
|
10,124 |
|
|
|
74,924 |
|
|
|
35,786 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
379,548 |
|
|
|
318,801 |
|
|
|
1,081,721 |
|
|
|
861,344 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
18,141 |
|
|
|
22,908 |
|
|
|
45,759 |
|
|
|
62,963 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(6,636 |
) |
|
|
(5,666 |
) |
|
|
(19,400 |
) |
|
|
(14,497 |
) |
|
Interest income
|
|
|
197 |
|
|
|
230 |
|
|
|
675 |
|
|
|
331 |
|
|
Miscellaneous income, net
|
|
|
50 |
|
|
|
154 |
|
|
|
40 |
|
|
|
517 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(6,389 |
) |
|
|
(5,282 |
) |
|
|
(18,685 |
) |
|
|
(13,649 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations before income taxes and
minority interest
|
|
|
11,752 |
|
|
|
17,626 |
|
|
|
27,074 |
|
|
|
49,314 |
|
Income tax expense
|
|
|
3,542 |
|
|
|
2,379 |
|
|
|
15,141 |
|
|
|
5,852 |
|
Minority interest
|
|
|
|
|
|
|
7,980 |
|
|
|
2,918 |
|
|
|
22,335 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
8,210 |
|
|
|
7,267 |
|
|
|
9,015 |
|
|
|
21,127 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discontinued operations (note 11):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations before income taxes and
minority interest (including gain on disposal in April 2005 of
$704)
|
|
|
|
|
|
|
(5,248 |
) |
|
|
(379 |
) |
|
|
(6,120 |
) |
|
Income tax benefit
|
|
|
|
|
|
|
(1,024 |
) |
|
|
(93 |
) |
|
|
(1,120 |
) |
|
Minority interest
|
|
|
|
|
|
|
(2,378 |
) |
|
|
(72 |
) |
|
|
(2,773 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
(1,846 |
) |
|
|
(214 |
) |
|
|
(2,227 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
8,210 |
|
|
$ |
5,421 |
|
|
$ |
8,801 |
|
|
$ |
18,900 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per share, as adjusted (note 2):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.13 |
|
|
$ |
0.49 |
|
|
$ |
0.17 |
|
|
$ |
1.43 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
(0.12 |
) |
|
|
(0.01 |
) |
|
|
(0.15 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income, as adjusted
|
|
$ |
0.13 |
|
|
$ |
0.37 |
|
|
$ |
0.16 |
|
|
$ |
1.28 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.13 |
|
|
$ |
0.49 |
|
|
$ |
0.17 |
|
|
$ |
1.43 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
(0.12 |
) |
|
|
(0.01 |
) |
|
|
(0.15 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income, as adjusted
|
|
$ |
0.13 |
|
|
$ |
0.37 |
|
|
$ |
0.16 |
|
|
$ |
1.28 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per share (note 2):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
$ |
0.19 |
|
|
$ |
0.18 |
|
|
$ |
0.53 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
(0.05 |
) |
|
|
|
|
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
|
|
|
|
$ |
0.14 |
|
|
$ |
0.18 |
|
|
$ |
0.47 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
|
|
|
|
$ |
0.19 |
|
|
$ |
0.18 |
|
|
$ |
0.52 |
|
|
|
Loss from discontinued operations
|
|
|
|
|
|
|
(0.05 |
) |
|
|
|
|
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
|
|
|
|
$ |
0.14 |
|
|
$ |
0.18 |
|
|
$ |
0.46 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to condensed consolidated financial
statements.
F-4
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF STOCKHOLDERS EQUITY
(Unaudited)
NINE MONTHS ENDED SEPTEMBER 30, 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ANR | |
|
|
|
|
Alpha Natural Resources, Inc. | |
|
Alpha NR Holding, Inc. | |
|
Fund IX | |
|
|
|
|
| |
|
| |
|
Holdings, | |
|
|
|
|
|
|
|
|
L.P. | |
|
Total | |
|
|
|
|
|
|
|
|
| |
|
Stockholders | |
|
|
Common Stock | |
|
Additional | |
|
Unearned | |
|
|
|
Total | |
|
|
|
Additional | |
|
|
|
Total | |
|
|
|
Equity and | |
|
|
| |
|
Paid-In | |
|
Stock-based | |
|
Accumulated |
|
Stockholders | |
|
Common |
|
Paid-In | |
|
Retained | |
|
Stockholders | |
|
Partners | |
|
Partners | |
|
|
Shares | |
|
Amount | |
|
Capital | |
|
Compensation | |
|
Deficit |
|
Equity | |
|
Stock |
|
Capital | |
|
Earnings | |
|
Equity | |
|
Capital | |
|
Capital | |
|
|
| |
|
| |
|
| |
|
| |
|
|
|
| |
|
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per share amounts) | |
Balances, December 31, 2003
|
|
|
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
75,710 |
|
|
$ |
1,442 |
|
|
$ |
77,152 |
|
|
$ |
9,215 |
|
|
$ |
86,367 |
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17,386 |
|
|
|
17,386 |
|
|
|
2,629 |
|
|
|
20,015 |
|
Noncash distribution of Virginia Tax Credit
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(292 |
) |
|
|
(292 |
) |
Distributions
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(53,557 |
) |
|
|
|
|
|
|
(53,557 |
) |
|
|
(6,600 |
) |
|
|
(60,157 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
22,153 |
|
|
|
18,828 |
|
|
|
40,981 |
|
|
|
4,952 |
|
|
|
45,933 |
|
Noncash distribution of Virginia Tax Credit
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(40 |
) |
|
|
(40 |
) |
Net income prior to Internal Restructuring
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,320 |
|
|
|
2,320 |
|
|
|
379 |
|
|
|
2,699 |
|
Distribution to First Reserve Fund IX, L.P. and ANR
Fund IX Holdings, L.P. prior to the Internal Restructuring
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(8,160 |
) |
|
|
(8,160 |
) |
|
|
(1,243 |
) |
|
|
(9,403 |
) |
Contribution by First Reserve Fund IX, L.P. of all of the
outstanding common stock of Alpha NR Holding, Inc. in exchange
for shares of Alpha Natural Resources, Inc. common stock
|
|
|
12,463 |
|
|
|
125 |
|
|
|
35,016 |
|
|
|
|
|
|
|
|
|
|
|
35,141 |
|
|
|
|
|
|
|
(22,153 |
) |
|
|
(12,988 |
) |
|
|
(35,141 |
) |
|
|
|
|
|
|
|
|
Contribution by ANR Fund IX Holdings, L.P. of its
membership interest in ANR Holdings, LLC in exchange for shares
of Alpha Natural Resources, Inc. common stock upon completion of
the Internal Restructuring
|
|
|
1,536 |
|
|
|
15 |
|
|
|
4,033 |
|
|
|
|
|
|
|
|
|
|
|
4,048 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,048 |
) |
|
|
|
|
Contribution by minority interest holders, including certain
members of management, of their membership interests in ANR
Holdings, LLC in exchange for shares of Alpha Natural Resources,
Inc. common stock and recognition of unearned stock-based
compensation
|
|
|
14,289 |
|
|
|
143 |
|
|
|
85,424 |
|
|
|
(29,122 |
) |
|
|
|
|
|
|
56,445 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
56,445 |
|
Issuance of Restructuring Notes
|
|
|
|
|
|
|
|
|
|
|
(517,692 |
) |
|
|
|
|
|
|
|
|
|
|
(517,692 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(517,692 |
) |
Tax Distributions payable recorded upon the completion of the
Internal Restructuring
|
|
|
|
|
|
|
|
|
|
|
(10,500 |
) |
|
|
|
|
|
|
|
|
|
|
(10,500 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(10,500 |
) |
Change in net deferred income taxes recognized upon the
completion of the Internal Restructuring
|
|
|
|
|
|
|
|
|
|
|
25,729 |
|
|
|
|
|
|
|
|
|
|
|
25,729 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
25,729 |
|
Proceeds from initial public offering of common shares
($19 per share), net of offering costs of $48,296
|
|
|
33,925 |
|
|
|
339 |
|
|
|
595,940 |
|
|
|
|
|
|
|
|
|
|
|
596,279 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
596,279 |
|
F-5
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF STOCKHOLDERS EQUITY
(Unaudited) Continued
NINE MONTHS ENDED SEPTEMBER 30, 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ANR |
|
|
|
|
Alpha Natural Resources, Inc. | |
|
Alpha NR Holding, Inc. |
|
Fund IX |
|
|
|
|
| |
|
|
|
Holdings, |
|
|
|
|
|
|
|
|
L.P. |
|
Total | |
|
|
|
|
|
|
|
|
|
|
Stockholders | |
|
|
Common Stock | |
|
Additional | |
|
Unearned | |
|
|
|
Total | |
|
|
|
Additional |
|
|
|
Total |
|
|
|
Equity and | |
|
|
| |
|
Paid-In | |
|
Stock-based | |
|
Accumulated | |
|
Stockholders | |
|
Common |
|
Paid-In |
|
Retained |
|
Stockholders |
|
Partners |
|
Partners | |
|
|
Shares | |
|
Amount | |
|
Capital | |
|
Compensation | |
|
Deficit | |
|
Equity | |
|
Stock |
|
Capital |
|
Earnings |
|
Equity |
|
Capital |
|
Capital | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
|
| |
|
|
(In thousands, except per share amounts) | |
Distribution of net proceeds received from underwriters
exercise of over- allotment option
|
|
|
|
|
|
|
|
|
|
|
(71,135 |
) |
|
|
|
|
|
|
|
|
|
|
(71,135 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(71,135 |
) |
Amortization of unearned stock-based compensation
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10,056 |
|
|
|
|
|
|
|
10,056 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10,056 |
|
Cancellation of nonvested stock options
|
|
|
|
|
|
|
|
|
|
|
(443 |
) |
|
|
443 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income subsequent to Internal Restructuring
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,102 |
|
|
|
6,102 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,102 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, September 30, 2005
|
|
|
62,213 |
|
|
$ |
622 |
|
|
$ |
146,372 |
|
|
$ |
(18,623 |
) |
|
$ |
6,102 |
|
|
$ |
134,473 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
134,473 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to condensed consolidated financial
statements.
F-6
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
September 30, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
(In thousands) | |
Operating activities:
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
8,801 |
|
|
$ |
18,900 |
|
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
45,805 |
|
|
|
39,352 |
|
|
|
Amortization and write-off of debt issuance costs
|
|
|
1,325 |
|
|
|
4,039 |
|
|
|
Minority interest
|
|
|
2,846 |
|
|
|
19,562 |
|
|
|
Accretion of asset retirement obligation
|
|
|
2,463 |
|
|
|
2,902 |
|
|
|
Virginia tax credit
|
|
|
(343 |
) |
|
|
(1,930 |
) |
|
|
Stock-based compensation non-cash
|
|
|
35,694 |
|
|
|
|
|
|
|
Provision for bad debts
|
|
|
44 |
|
|
|
298 |
|
|
|
Amortization of deferred gains on sales of property interests
|
|
|
(595 |
) |
|
|
(690 |
) |
|
|
Amortization of deferred gain on railroad incentives
|
|
|
(478 |
) |
|
|
|
|
|
|
Loss on settlement of asset retirement obligation
|
|
|
490 |
|
|
|
636 |
|
|
|
Asset impairment charge
|
|
|
|
|
|
|
5,100 |
|
|
|
Write-off of advance royalties
|
|
|
|
|
|
|
1,099 |
|
|
|
Gains on sales of fixed assets, net
|
|
|
(11 |
) |
|
|
(342 |
) |
|
|
Gain on sale of discontinued operations
|
|
|
(704 |
) |
|
|
|
|
|
|
Deferred income taxes
|
|
|
2,668 |
|
|
|
2,448 |
|
|
|
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
Trade accounts receivable
|
|
|
(56,073 |
) |
|
|
(27,568 |
) |
|
|
|
Notes and other receivables
|
|
|
(1,087 |
) |
|
|
(183 |
) |
|
|
|
Inventories
|
|
|
(48,294 |
) |
|
|
(19,841 |
) |
|
|
|
Prepaid expenses and other current assets
|
|
|
13,438 |
|
|
|
9,478 |
|
|
|
|
Other assets
|
|
|
(5,148 |
) |
|
|
(1,497 |
) |
|
|
|
Trade accounts payable
|
|
|
20,868 |
|
|
|
18,534 |
|
|
|
|
Accrued expenses and other current liabilities
|
|
|
(4,691 |
) |
|
|
26,341 |
|
|
|
|
Workers compensation benefits
|
|
|
367 |
|
|
|
2,274 |
|
|
|
|
Postretirement medical benefits
|
|
|
6,589 |
|
|
|
2,828 |
|
|
|
|
Asset retirement obligation
|
|
|
(2,919 |
) |
|
|
(2,495 |
) |
|
|
|
Other liabilities
|
|
|
569 |
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
21,624 |
|
|
|
99,247 |
|
|
|
|
|
|
|
|
Investing activities:
|
|
|
|
|
|
|
|
|
|
Capital expenditures
|
|
|
(95,919 |
) |
|
|
(52,984 |
) |
|
Proceeds from disposal of property, plant and equipment
|
|
|
5,282 |
|
|
|
595 |
|
|
Purchase of net assets of acquired companies
|
|
|
(961 |
) |
|
|
(2,891 |
) |
|
Equity investments
|
|
|
(1,234 |
) |
|
|
(3,250 |
) |
|
Payment of additional consideration on acquisition
|
|
|
(5,000 |
) |
|
|
|
|
|
Issuance of note receivable to coal supplier
|
|
|
|
|
|
|
(10,000 |
) |
|
Collections on note receivable from coal supplier
|
|
|
4,442 |
|
|
|
675 |
|
|
Increase in due from affiliate
|
|
|
|
|
|
|
620 |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(93,390 |
) |
|
|
(67,235 |
) |
|
|
|
|
|
|
|
Financing activities:
|
|
|
|
|
|
|
|
|
|
Repayments of notes payable
|
|
|
(12,413 |
) |
|
|
(11,787 |
) |
|
Proceeds from issuance of long-term debt
|
|
|
73,000 |
|
|
|
175,000 |
|
|
Repayments on long-term debt
|
|
|
(1,323 |
) |
|
|
(64,920 |
) |
|
Increase in bank overdraft
|
|
|
5,483 |
|
|
|
396 |
|
|
Proceeds from initial public offering, net of offering costs
|
|
|
598,066 |
|
|
|
|
|
|
Repayment of restructuring notes payable
|
|
|
(517,692 |
) |
|
|
|
|
|
Distributions to prior members of ANR Holdings, LLC subsequent
to Internal Restructuring
|
|
|
(72,335 |
) |
|
|
|
|
|
Distributions to prior members of ANR Holdings, LLC prior to
Internal Restructuring
|
|
|
(7,732 |
) |
|
|
(115,573 |
) |
|
Debt issuance costs
|
|
|
(568 |
) |
|
|
(10,563 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities
|
|
|
64,486 |
|
|
|
(27,447 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and cash equivalents
|
|
|
(7,280 |
) |
|
|
4,565 |
|
Cash and cash equivalents at beginning of period
|
|
|
7,391 |
|
|
|
11,246 |
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$ |
111 |
|
|
$ |
15,811 |
|
|
|
|
|
|
|
|
See accompanying notes to condensed consolidated financial
statements.
F-7
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
September 30, 2005
(In thousands, except percentages and share data)
|
|
(1) |
Business and Basis of Presentation |
|
|
|
Organization and Business |
Alpha Natural Resources, Inc. and its operating subsidiaries are
engaged in the business of extracting, processing and marketing
coal from deep and surface mines, located in the Central and
Northern Appalachian regions of the United States, for sale to
utility and steel companies in the United States and in
international markets.
On February 11, 2005, Alpha Natural Resources, Inc., a
Delaware corporation (Alpha) succeeded to the business of ANR
Holdings, LLC, a Delaware limited liability company (ANR
Holdings) in a series of internal restructuring transactions
which are referred to collectively as the Internal
Restructuring, and on February 18, 2005, Alpha completed
the initial public offering of its common stock. Prior to the
Internal Restructuring, ANR Fund IX Holdings, L.P. and
Alpha NR Holding, Inc. (the FR Affiliates), entities under the
common control of First Reserve GP IX, Inc., were the owners of
54.7% of the membership interests in ANR Holdings, and the
remaining membership interests in ANR Holdings were held by
affiliates of American Metals & Coal International,
Inc. (AMCI), Alpha Coal Management, LLC (ACM) and Madison
Capital Funding, LLC. The financial statements for the nine
months ended September 30, 2005 are presented on a combined
basis including the combined financial results for the
FR Affiliates and subsidiaries for the period from
January 1, 2005 to February 11, 2005, and the
consolidated results for Alpha and subsidiaries from
February 12, 2005 to September 30, 2005. The financial
statements for the three months ended September 30, 2005
are presented on a consolidated basis. The financial statements
for the period from January 1, 2004 to September 30,
2004 and for the period from July 1, 2004 to
September 30, 2004 are presented for the FR Affiliates and
subsidiaries on a combined basis. The entities included in the
accompanying financial statements are collectively referred to
as the Company.
The accompanying interim condensed consolidated financial
statements have been prepared in accordance with U.S generally
accepted accounting principles for interim financial reporting.
Accounting measurements at interim dates inherently rely on
estimates more than year-end; however, in the opinion of
management, all adjustments (consisting of normal recurring
accruals) considered necessary for a fair presentation have been
included. Results of operations for the nine months ended
September 30, 2005 are not necessarily indicative of the
results to be expected for the year ending December 31,
2005. These financial statements should be read in conjunction
with the audited financial statements and related notes as of
and for the year ended December 31, 2004 included in the
Companys Annual Report on Form 10-K filed with the
Securities and Exchange Commission.
Certain prior period amounts have been reclassified to conform
to the current year presentation with no effect on previously
reported net income.
Basic earnings per share is computed by dividing net income or
loss by the weighted average number of shares of common stock
outstanding during the periods. Diluted earnings per share is
computed by dividing net income or loss by the weighted average
number of shares of common stock and dilutive common stock
equivalents outstanding during the periods. Common stock
equivalents include the number of shares issuable on exercise of
outstanding options less the number of shares that could have
been
F-8
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
purchased with the proceeds from the exercise of the options
based on the average price of common stock during the period.
Due to the Internal Restructuring on February 11, 2005 and
initial public offering of common stock completed on
February 18, 2005, the Company has disclosed for
informational purposes two sets of earnings per share data on
the face of the accompanying condensed consolidated statements
of operations.
|
|
|
Net Income (Loss) Per Share, as Adjusted |
The first set of earnings per share data is labeled net
income (loss) per share, as adjusted. The numerator for
purposes of computing basic and diluted net income (loss) per
share, as adjusted, includes the reported net income (loss) and
a pro forma adjustment for income taxes to reflect the pro forma
income taxes for ANR Fund IX Holdings, L.P.s portion
of reported pre-tax income (loss), which would have been
recorded if the issuance of the shares of common stock received
by the FR Affiliates in exchange for their ownership in ANR
Holdings in connection with the Internal Restructuring had
occurred as of January 1, 2004. For purposes of the
computation of basic and diluted net income (loss) per share, as
adjusted, the pro forma adjustment for income taxes only applies
to the percentage interest owned by ANR Fund IX Holding,
L.P., the non-taxable FR Affiliate. No pro forma adjustment for
income taxes is required for the percentage interest owned by
Alpha NR Holding, Inc., the taxable FR Affiliate, because income
taxes have already been recorded in the historical results of
operations. Furthermore, no pro forma adjustment to reported net
income (loss) is necessary subsequent to February 11, 2005
because Alpha is subject to income taxes.
The denominator for purposes of computing basic net income
(loss) per share, as adjusted, reflects the retroactive impact
of the common shares received by the FR Affiliates in exchange
for their ownership in ANR Holdings in connection with the
Internal Restructuring on a weighted-average outstanding share
basis as being outstanding as of January 1, 2004. The
common shares issued to the minority interest owners of ANR
Holdings in connection with the Internal Restructuring,
including the immediately vested shares granted to management,
have been reflected as being outstanding as of February 11,
2005 for purposes of computing the basic net income (loss) per
share, as adjusted. The unvested shares granted to management on
February 11, 2005 that vest monthly over the two-year
period from January 1, 2005 to December 31, 2006 are
included in the basic net income (loss) per share, as adjusted,
computation as they vest on a weighted-average outstanding share
basis starting on February 11, 2005. The 33,925,000 new
shares issued in connection with the initial public offering
have been reflected as being outstanding since February 14,
2005, the date of the initial public offering, for purposes of
computing the basic net income (loss) per share, as adjusted.
The unvested shares issued to management are considered options
for purposes of computing diluted net income (loss) per share,
as adjusted. Therefore, for diluted purposes, all remaining
unvested shares granted to management are added to the
denominator subsequent to February 11, 2005 using the
treasury stock method, if the effect is dilutive. In addition,
the treasury stock method is used for outstanding stock options,
if dilutive, beginning with the November 10, 2004 grant of
options to management to purchase units in ACM that were
automatically converted into options to purchase up to
596,985 shares of Alpha Natural Resources, Inc. common
stock at an exercise price of $12.73 per share.
F-9
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
The computations of basic and diluted net income (loss) per
share, as adjusted, are set forth below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
Nine Months Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported income from continuing operations
|
|
$ |
8,210 |
|
|
$ |
7,267 |
|
|
$ |
9,015 |
|
|
$ |
21,127 |
|
|
Deduct: Income tax effect of ANR Fund IX Holdings, L.P.
income from continuing operations prior to Internal Restructuring
|
|
|
|
|
|
|
(402 |
) |
|
|
(91 |
) |
|
|
(1,124 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
|
8,210 |
|
|
|
6,865 |
|
|
|
8,924 |
|
|
|
20,003 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported loss from discontinued operations
|
|
|
|
|
|
|
(1,846 |
) |
|
|
(214 |
) |
|
|
(2,227 |
) |
|
Add: Income tax effect of ANR Fund IX Holdings, L.P. loss
from discontinued operations prior to Internal Restructuring
|
|
|
|
|
|
|
120 |
|
|
|
2 |
|
|
|
139 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations, as adjusted
|
|
|
|
|
|
|
(1,726 |
) |
|
|
(212 |
) |
|
|
(2,088 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income, as adjusted
|
|
$ |
8,210 |
|
|
$ |
5,139 |
|
|
$ |
8,712 |
|
|
$ |
17,915 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares denominator for basic
|
|
|
61,259,314 |
|
|
|
13,998,911 |
|
|
|
53,184,066 |
|
|
|
13,998,911 |
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
648,706 |
|
|
|
|
|
|
|
382,403 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted weighted average shares for diluted
|
|
|
61,908,020 |
|
|
|
13,998,911 |
|
|
|
53,566,469 |
|
|
|
13,998,911 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
$ |
0.13 |
|
|
$ |
0.49 |
|
|
$ |
0.17 |
|
|
$ |
1.43 |
|
|
Loss from discontinued operations, as adjusted
|
|
|
|
|
|
|
(0.12 |
) |
|
|
(0.01 |
) |
|
|
(0.15 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per basic share, as adjusted
|
|
$ |
0.13 |
|
|
$ |
0.37 |
|
|
$ |
0.16 |
|
|
$ |
1.28 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per diluted share, as adjusted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations, as adjusted
|
|
$ |
0.13 |
|
|
$ |
0.49 |
|
|
$ |
0.17 |
|
|
$ |
1.43 |
|
|
Loss from discontinued operations, as adjusted
|
|
|
|
|
|
|
(0.12 |
) |
|
|
(0.01 |
) |
|
|
(0.15 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per diluted share, as adjusted
|
|
$ |
0.13 |
|
|
$ |
0.37 |
|
|
$ |
0.16 |
|
|
$ |
1.28 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-10
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
|
|
|
Pro Forma Net Income (Loss) Per Share |
The second set of earnings per share data is labeled pro
forma net income (loss) per share. The numerator for
purposes of computing basic and diluted pro forma net income
(loss) per share includes the reported net income (loss) and pro
forma adjustments to reflect the impact of:
|
|
|
(i) the additional income taxes on the portion of reported
pre-tax income (loss) attributable to the portion owned by ANR
Fund IX Holdings, L.P. for the periods from January 1,
2005 to February 11, 2005, and from January 1, 2004 to
September 30, 2004; |
|
|
(ii) the add back of minority interest for the periods from
January 1, 2005 to February 11, 2005, and from
January 1, 2004 to September 30, 2004 because the
ownership held by the minority interest owners of ANR Holdings
were exchanged for shares of Alpha National Resources, Inc. as
part of the Internal Restructuring; |
|
|
(iii) the additional income taxes that would have been
incurred by the Company on the minority interest added back for
the periods from January 1, 2005 to February 11, 2005,
and from January 1, 2004 to September 30,
2004; and |
|
|
(iv) the issuance of $175,000 principal amount of
10% senior notes due 2012 by our subsidiaries Alpha Natural
Resources, LLC and Alpha Natural Resources Capital Corp. and the
entry by Alpha Natural Resources, LLC into a $175,000 credit
facility in May 2004, which we refer to as the 2004 Financings,
as if these transactions had occurred on January 1, 2004. |
No pro forma adjustments to reported net income (loss) are
necessary subsequent to February 11, 2005.
The denominator for purposes of computing basic pro forma net
income (loss) per share reflects:
|
|
|
(i) the retroactive impact of the common shares received by
the FR Affiliates in exchange for their ownership in ANR
Holdings in connection with the Internal Restructuring on a
weighted-average outstanding share basis as being outstanding as
of January 1, 2004; |
|
|
(ii) the retroactive impact of the common shares issued to
the minority interest owners of ANR Holdings in connection
with the Internal Restructuring, including the immediately
vested shares granted to management, on a weighted-average
outstanding share basis as being outstanding as of
January 1, 2004; |
|
|
(iii) the unvested shares granted to management that vest
over the two-year period from January 1, 2005 to
December 31, 2006 have been included in the basic
computation on a weighted-average outstanding share basis which
is based on the monthly vesting beginning as of January 1,
2005; and |
|
|
(iv) the retroactive impact of the 33,925,000 new shares
issued in connection with the initial public offering on a
weighted-average outstanding share basis as being outstanding as
of January 1, 2004 since 100 percent of the net
proceeds from the initial public offering was distributed to the
previous owners of ANR Holdings. |
The unvested shares issued to management are considered options
for purposes of computing diluted pro forma net income (loss)
per share. Therefore, for diluted purposes, all remaining
unvested shares granted to management would be added to the
denominator as of January 1, 2004 using the treasury stock
method, if the effect is dilutive. In addition, the treasury
stock method would be used for outstanding stock options, if
dilutive, beginning with the November 10, 2004 grant of
options to management to purchase units in ACM that were
automatically converted into options to purchase up to
596,985 shares of Alpha Natural Resources, Inc. common
stock at an exercise price of $12.73 per share.
F-11
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
The following pro forma earnings per share data for the quarter
and nine months ended September 30, 2005 and 2004 give
effect to the 2004 Financings, the Internal Restructuring and
our initial public offering of common stock completed on
February 18, 2005 as if these transactions had occurred on
January 1, 2004. This pro forma information is for
information purposes only, and should not be considered
indicative of results that would have been achieved had the
transactions listed above actually been consummated on
January 1, 2004.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
Nine Months Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
Pro forma revenues
|
|
$ |
397,689 |
|
|
$ |
341,709 |
|
|
$ |
1,127,480 |
|
|
$ |
924,307 |
|
Pro forma net income
|
|
|
8,210 |
|
|
|
8,613 |
|
|
|
10,888 |
|
|
|
28,430 |
|
The computation of basic and diluted pro forma earnings (loss)
per share are set forth below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
|
|
September 30, | |
|
|
Three Months Ended | |
|
| |
|
|
September 30, 2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reported income from continuing operations
|
|
$ |
7,267 |
|
|
$ |
9,015 |
|
|
$ |
21,127 |
|
|
Deduct: Income tax effect of ANR Fund IX Holdings, L.P.
income from continuing operations prior to Internal Restructuring
|
|
|
(402 |
) |
|
|
(91 |
) |
|
|
(1,124 |
) |
|
Deduct: Pro forma effects of the 2004 Financings, net of income
taxes
|
|
|
|
|
|
|
|
|
|
|
(1,614 |
) |
|
Add: Minority interest in income from continuing operations, net
of income tax effect
|
|
|
4,948 |
|
|
|
2,231 |
|
|
|
13,848 |
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
|
11,813 |
|
|
|
11,155 |
|
|
|
32,237 |
|
|
|
|
|
|
|
|
|
|
|
|
Reported income loss from discontinued operations
|
|
|
(1,846 |
) |
|
|
(214 |
) |
|
|
(2,227 |
) |
|
Add: Income tax effect of ANR Fund IX Holdings, L.P. loss
from discontinued operations prior to Internal Restructuring
|
|
|
120 |
|
|
|
2 |
|
|
|
139 |
|
|
Add: Minority interest in loss from discontinued operations, net
of income tax effect
|
|
|
(1,474 |
) |
|
|
(55 |
) |
|
|
(1,719 |
) |
|
|
|
|
|
|
|
|
|
|
|
Pro forma loss from discontinued operations
|
|
|
(3,200 |
) |
|
|
(267 |
) |
|
|
(3,807 |
) |
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
$ |
8,613 |
|
|
$ |
10,888 |
|
|
$ |
28,430 |
|
|
|
|
|
|
|
|
|
|
|
Pro forma denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares denominator for basic
|
|
|
60,867,650 |
|
|
|
61,092,832 |
|
|
|
60,867,650 |
|
|
Dilutive effect of stock options and restricted stock grants
|
|
|
444,201 |
|
|
|
584,389 |
|
|
|
379,183 |
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted weighted average shares for diluted
|
|
|
61,311,851 |
|
|
|
61,677,221 |
|
|
|
61,246,833 |
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per basic share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
$ |
0.19 |
|
|
$ |
0.18 |
|
|
$ |
0.53 |
|
|
Pro forma loss from discontinued operations
|
|
|
(0.05 |
) |
|
|
|
|
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per basic share
|
|
$ |
0.14 |
|
|
$ |
0.18 |
|
|
$ |
0.47 |
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per diluted share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
$ |
0.19 |
|
|
$ |
0.18 |
|
|
$ |
0.52 |
|
|
Pro forma income loss from discontinued operations
|
|
|
(0.05 |
) |
|
|
|
|
|
|
(0.06 |
) |
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per diluted share
|
|
$ |
0.14 |
|
|
$ |
0.18 |
|
|
$ |
0.46 |
|
|
|
|
|
|
|
|
|
|
|
F-12
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
|
|
|
Pro Forma Earnings Per Share Disclosure Provisions of
SFAS No. 123 |
The Company accounts for stock-based compensation awards granted
to employees in accordance with Accounting Principles Board
(APB) Opinion No. 25, Accounting for Stock Issued
to Employees, and related interpretations. Compensation cost
for equity-based awards is recognized in an amount equal to the
difference between the exercise price of the award and the fair
value of the Companys common stock on the date of grant.
The Company has implemented the disclosure-only provisions of
SFAS No. 123 Accounting for Stock-Based
Compensation. The following table illustrates the
effect on pro forma net income as if the Company had applied the
fair value recognition provisions of SFAS No. 123 to
equity-based employee compensation using the Black-Scholes
option-pricing model for the three and nine months ended
September 30, 2005:
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Nine Months | |
|
|
Ended | |
|
Ended | |
|
|
September 30, 2005 | |
|
September 30, 2005 | |
|
|
| |
|
| |
Net income (pro forma net income for the nine months ended
September 30, 2005)
|
|
$ |
8,210 |
|
|
$ |
10,888 |
|
Add: Stock-based compensation expense included in pro forma net
income, net of income taxes
|
|
|
2,362 |
|
|
|
40,391 |
|
Deduct: Total stock-based compensation expense determined under
fair-value based method, net of income taxes
|
|
|
(2,572 |
) |
|
|
(40,945 |
) |
|
|
|
|
|
|
|
Pro forma net income, adjusted for effect of fair value of stock
options
|
|
$ |
8,000 |
|
|
$ |
10,334 |
|
|
|
|
|
|
|
|
Income per share:
|
|
|
|
|
|
|
|
|
|
Basic and diluted pro forma (see above)
|
|
$ |
0.13 |
|
|
$ |
0.18 |
|
|
Basic and diluted pro forma, adjusted
|
|
$ |
0.13 |
|
|
$ |
0.17 |
|
The Company had not granted equity-based awards prior to
November 2004. The fair value of equity-based awards granted in
November 2004 and in the first nine months of 2005 was estimated
on the date of the grant using the Black-Scholes option pricing
model with the following weighted average assumptions:
|
|
|
|
|
Expected life (years)
|
|
|
4.0 |
|
Expected volatility
|
|
|
38.0 |
% |
Risk-free interest rate
|
|
|
3.38 |
% |
Expected annual dividend
|
|
$ |
0.10 |
|
The effects on pro forma net income of expensing the estimated
fair value of equity-based awards are not necessarily
representative of the effects on reported net income for future
periods due to such factors as the vesting periods of stock
options and the potential issuance of additional awards in
future years.
F-13
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
Inventories consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Raw coal
|
|
$ |
5,473 |
|
|
$ |
3,888 |
|
Saleable coal
|
|
|
87,982 |
|
|
|
42,899 |
|
Materials and supplies
|
|
|
9,401 |
|
|
|
7,782 |
|
|
|
|
|
|
|
|
|
Total inventories
|
|
$ |
102,856 |
|
|
$ |
54,569 |
|
|
|
|
|
|
|
|
Long-term debt consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
10% Senior notes due 2012
|
|
$ |
175,000 |
|
|
$ |
175,000 |
|
Revolving credit facility
|
|
|
81,000 |
|
|
|
8,000 |
|
Variable rate term notes
|
|
|
586 |
|
|
|
1,466 |
|
Capital lease obligation
|
|
|
1,623 |
|
|
|
1,995 |
|
Other
|
|
|
|
|
|
|
16 |
|
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
|
258,209 |
|
|
|
186,477 |
|
|
Less current portion
|
|
|
1,046 |
|
|
|
1,693 |
|
|
|
|
|
|
|
|
|
|
Long-term debt, net of current portion
|
|
$ |
257,163 |
|
|
$ |
184,784 |
|
|
|
|
|
|
|
|
The $175,000 of 10% senior notes issued by our indirect
subsidiary, Alpha Natural Resources, LLC and its wholly-owned
subsidiary, Alpha Natural Resources Capital Corp., are unsecured
but are guaranteed fully and unconditionally on a joint and
several basis by all of our subsidiaries other than the issuers
of the notes.
Alpha Natural Resources, LLC has a revolving credit facility
with a group of lending institutions led by Citicorp North
America, Inc., as administrative agent (Citicorp Credit
Facility). The Citicorp Credit Facility, as amended, provides
for a revolving line of credit of up to $125,000 and a funded
letter of credit facility of up to $50,000. As of
September 30, 2005, Alpha Natural Resources, LLC had
$81,000 principal amount of borrowings outstanding under its
$125,000 revolving line of credit and $2,966 in letters of
credit outstanding, leaving $41,034 available for borrowing. The
weighted average interest rate applicable to borrowings under
the revolver was 6.8% as of September 30, 2005. As of
September 30, 2005, the funded letter of credit facility
was fully utilized at $50,000 at an annual fee of 3.1% of the
outstanding amount. Each of the Companys subsidiaries
other than Alpha Natural Resources, LLC has guaranteed Alpha
Natural Resources, LLCs obligations under the revolving
credit facility. The obligations of Alphas subsidiaries
under the Citicorp Credit Facility are collateralized by all of
their assets. The Citicorp Credit Facility contains various
affirmative and negative covenants which, among others,
establish net worth, interest coverage and leverage ratio
requirements. Alpha Natural Resources, LLC must pay an annual
commitment fee up to a maximum of 1/2 of 1% of the unused
portion of the commitment. Alphas subsidiaries were in
compliance with their debt covenants under the Citicorp Credit
Facility as of September 30, 2005. See Note 14 for a
description of the New Citicorp Credit Facility, which was used
to refinance borrowings under the Citicorp Credit Facility
described above.
F-14
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
|
|
(5) |
Asset Retirement Obligation |
At September 30, 2005 and December 31, 2004, the
Company has recorded asset retirement obligation accruals for
mine reclamation and closure costs totaling $40,975 and $39,579,
respectively. The portion of the costs expected to be incurred
within a year in the amount of $6,691 at September 30, 2005
and December 31, 2004 is included in accrued expenses and
other current liabilities. These regulatory obligations are
secured by surety bonds in the amount of $89,290 at
September 30, 2005 and $91,394 at December 31, 2004.
Changes in the reclamation obligation were as follows:
|
|
|
|
|
|
|
Total asset retirement obligation at December 31, 2004
|
|
$ |
39,579 |
|
Accretion for the nine months ended September 30, 2005
|
|
|
2,463 |
|
Sites added during the nine months ended September 30, 2005
|
|
|
1,156 |
|
Expenditures for the nine months ended September 30, 2005
|
|
|
(2,919 |
) |
Loss on settlement of asset retirement obligation
|
|
|
371 |
|
Revision to estimate
|
|
|
325 |
|
|
|
|
|
|
Total asset retirement obligation at September 30, 2005
|
|
$ |
40,975 |
|
|
|
|
|
|
|
(6) |
Stock-Based Compensation Awards |
The Company accounts for stock-based compensation awards granted
to employees in accordance with Accounting Principles Board
(APB) Opinion No. 25, Accounting for Stock Issued
to Employees, and related interpretations. Compensation cost
for equity-based awards is recognized in an amount equal to the
difference between the exercise price of the award and the fair
value of the Companys equity on the date of grant. In
accordance with APB Opinion No. 25, the Company recognized
compensation expense of $3,381 and $43,169 related to the three
and nine months ended September 30, 2005, respectively, for
equity-based awards that had an exercise or issuance price less
than the fair value of the Companys common shares on the
grant or issue date.
At September 30, 2005 there were 1,269,194 stock options
outstanding, with a weighted average exercise price of $16.66
and a weighted average remaining contractual life of
9.3 years. None of these options were exercisable as of
September 30, 2005. The following table summarizes stock
option activity for the nine months ended September 30,
2005 and the options outstanding at September 30, 2005:
|
|
|
|
|
|
|
|
|
|
|
Number of | |
|
Exercise | |
|
|
Options | |
|
Price | |
|
|
| |
|
| |
Outstanding at January 1, 2005
|
|
|
596,985 |
|
|
$ |
12.73 |
|
Granted at initial public offering
|
|
|
692,905 |
|
|
$ |
19.00 |
|
Additional grants
|
|
|
70,000 |
|
|
$ |
23.69 |
|
Exercised
|
|
|
|
|
|
|
|
|
Forfeited
|
|
|
(90,696 |
) |
|
$ |
14.11 |
|
|
|
|
|
|
|
|
Outstanding at September 30, 2005
|
|
|
1,269,194 |
|
|
$ |
16.66 |
|
|
|
|
|
|
|
|
F-15
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
|
|
(7) |
Postretirement Benefits Other Than Pensions |
The following table details the components of the net periodic
benefit cost for postretirement benefits other than pensions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Nine Months | |
|
|
Ended | |
|
Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
Service cost
|
|
$ |
940 |
|
|
$ |
925 |
|
|
$ |
2,884 |
|
|
$ |
1,323 |
|
Interest cost
|
|
|
601 |
|
|
|
525 |
|
|
|
1,856 |
|
|
|
837 |
|
Amortization of net (gain) or loss
|
|
|
10 |
|
|
|
(6 |
) |
|
|
19 |
|
|
|
(18 |
) |
Amortization of prior service cost
|
|
|
535 |
|
|
|
698 |
|
|
|
1,841 |
|
|
|
698 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic benefit cost
|
|
$ |
2,086 |
|
|
$ |
2,142 |
|
|
$ |
6,600 |
|
|
$ |
2,840 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employer contributions for benefits paid for the nine months
ended September 30, 2005 and 2004 were $11 and $29,
respectively. Employee contributions are not expected to be made
and the plan is unfunded.
Two of the Companys subsidiaries are required to make
contributions to the 1993 UMWA Benefit Plan of fifty cents per
signatory hour worked. The contributions that the Company made
to this plan for the quarters ended September 30, 2005 and
2004 were $9 and $8, respectively and $24 and $24 for the nine
months ended September 30, 2005 and 2004, respectively.
|
|
(8) |
Related Party Transactions |
The Company had the following receivable balances from
affiliated parties as of September 30, 2005 and
December 31, 2004:
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
AMCI
|
|
$ |
14,271 |
|
|
$ |
7,121 |
|
Robindale Energy & Subsidiary
|
|
|
34 |
|
|
|
6 |
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
14,305 |
|
|
$ |
7,127 |
|
|
|
|
|
|
|
|
As of September 30, 2005, $13,206 of receivables from AMCI
are included in trade accounts receivable, net and $1,065 is
included in notes and other receivables. As of December 31,
2004, all receivables from AMCI were included in trade accounts
receivable. The majority of the AMCI receivables as of
September 30, 2005 and December 31, 2004 relate to
coal sales transactions in the normal course of business.
The Company had the following balances payable to affiliated
parties as of September 30, 2005 and December 31, 2004:
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
AMCI
|
|
$ |
2,400 |
|
|
$ |
262 |
|
First Reserve Fund IX, L.P.
|
|
|
4,500 |
|
|
|
|
|
Robindale Energy & Subsidiary
|
|
|
139 |
|
|
|
42 |
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
7,039 |
|
|
$ |
304 |
|
|
|
|
|
|
|
|
F-16
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
As of September 30, 2005, $2,400 of AMCI payables is
included in accrued expenses and other current liabilities, and
$4,500 of payables to First Reserve Fund IX, L.P. is
included in other liabilities. These represent tax distributions
payable, related to the Internal Restructuring on
February 11, 2005. Also as of September 30, 2005, $139
owed to Robindale Energy & Subsidiary related to
trucking and coal purchases and is included in trade accounts
payable. As of December 31, 2004, $262, related to building
rent, is included in accrued expenses and other current
liabilities and $42 payable to Robindale Energy &
Subsidiary is included in trade accounts payable.
The Company extracts, processes and markets steam and
metallurgical coal from surface and deep mines for sale to
electric utilities, steel and coke producers, and industrial
customers. The Company operates only in the United States with
mines in the Central Appalachian and Northern Appalachian
regions. The Company has one reportable segment: Coal
Operations, which as of September 30, 2005, consisted of 45
underground mines and 22 surface mines located in Central
Appalachia and Northern Appalachia. Coal Operations also
includes the Companys purchased coal sales function, which
markets the Companys Appalachian coal to domestic and
international customers. The All Other category includes the
Companys equipment sales and repair operations, as well as
other ancillary business activities, including terminal
services, coal and environmental analysis services, and leasing
of mineral rights. The Corporate and Eliminations category
includes general corporate overhead and the elimination of
intercompany transactions. The revenue elimination amount
represents inter-segment revenues. The Company evaluates the
performance of its segment based on EBITDA, as adjusted, which
the Company defines as net income (loss) plus interest expense,
income tax expense (benefit), depreciation, depletion and
amortization, less interest income, and adjusted for minority
interest. EBITDA, as adjusted, from continuing operations is
defined as income from continuing operations plus interest
expense, income tax expense (benefit), depreciation, depletion
and amortization, less interest income, and adjusted for
minority interest.
Operating segment results for continuing operations for the
three months ended September 30, 2005 and segment assets as
of September 30, 2005 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
394,331 |
|
|
$ |
9,084 |
|
|
$ |
(5,726 |
) |
|
$ |
397,689 |
|
Depreciation, depletion, and amortization
|
|
|
15,543 |
|
|
|
361 |
|
|
|
373 |
|
|
|
16,277 |
|
EBITDA, as adjusted
|
|
|
46,144 |
|
|
|
468 |
|
|
|
(12,144 |
) |
|
|
34,468 |
|
Capital expenditures
|
|
|
29,312 |
|
|
|
|
|
|
|
86 |
|
|
|
29,398 |
|
Total assets
|
|
|
536,792 |
|
|
|
72,019 |
|
|
|
13,287 |
|
|
|
622,098 |
|
Operating segment results for continuing operations for the nine
months ended September 30, 2005 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
1,116,447 |
|
|
$ |
29,313 |
|
|
$ |
(18,280 |
) |
|
$ |
1,127,480 |
|
Depreciation, depletion, and amortization
|
|
|
43,037 |
|
|
|
1,149 |
|
|
|
1,335 |
|
|
|
45,521 |
|
EBITDA, as adjusted
|
|
|
162,519 |
|
|
|
2,809 |
|
|
|
(74,008 |
) |
|
|
91,320 |
|
Capital expenditures
|
|
|
94,770 |
|
|
|
322 |
|
|
|
517 |
|
|
|
95,609 |
|
F-17
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
Operating segment results for continuing operations for the
three months ended September 30, 2004 and segment assets as
of September 30, 2004 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
337,950 |
|
|
$ |
6,771 |
|
|
$ |
(3,012 |
) |
|
$ |
341,709 |
|
Depreciation, depletion, and amortization
|
|
|
13,447 |
|
|
|
246 |
|
|
|
500 |
|
|
|
14,193 |
|
EBITDA, as adjusted
|
|
|
47,039 |
|
|
|
351 |
|
|
|
(10,135 |
) |
|
|
37,255 |
|
Capital expenditures
|
|
|
18,918 |
|
|
|
105 |
|
|
|
116 |
|
|
|
19,139 |
|
Total assets
|
|
|
390,341 |
|
|
|
76,337 |
|
|
|
(8,855 |
) |
|
|
457,823 |
|
Operating segment results for continuing operations for the nine
months ended September 30, 2004 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
912,810 |
|
|
$ |
20,111 |
|
|
$ |
(8,614 |
) |
|
$ |
924,307 |
|
Depreciation, depletion, and amortization
|
|
|
36,652 |
|
|
|
740 |
|
|
|
1,491 |
|
|
|
38,883 |
|
EBITDA, as adjusted
|
|
|
135,943 |
|
|
|
2,191 |
|
|
|
(35,771 |
) |
|
|
102,363 |
|
Capital expenditures
|
|
|
51,787 |
|
|
|
248 |
|
|
|
449 |
|
|
|
52,484 |
|
Reconciliation of total segment EBITDA, as adjusted, to income
from continuing operations follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
Nine Months Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
Total segment EBITDA, as adjusted, from continuing operations
|
|
$ |
34,468 |
|
|
$ |
37,255 |
|
|
$ |
91,320 |
|
|
$ |
102,363 |
|
Interest expense
|
|
|
(6,636 |
) |
|
|
(5,666 |
) |
|
|
(19,400 |
) |
|
|
(14,497 |
) |
Interest income
|
|
|
197 |
|
|
|
230 |
|
|
|
675 |
|
|
|
331 |
|
Income tax expense from continuing operations
|
|
|
(3,542 |
) |
|
|
(2,379 |
) |
|
|
(15,141 |
) |
|
|
(5,852 |
) |
Depreciation, depletion and amortization from continuing
operations
|
|
|
(16,277 |
) |
|
|
(14,193 |
) |
|
|
(45,521 |
) |
|
|
(38,883 |
) |
Minority interest in income from continuing operations
|
|
|
|
|
|
|
(7,980 |
) |
|
|
(2,918 |
) |
|
|
(22,335 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
8,210 |
|
|
$ |
7,267 |
|
|
$ |
9,015 |
|
|
$ |
21,127 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The Company markets produced, processed and purchased coal to
customers in the United States and in international markets.
Export revenues totaled $156,243 and $501,014 or approximately
39% and 44% of total revenues for the three and nine months
ended September 30, 2005, respectively. Export revenues
were $171,971 and $447,513 or approximately 50% and 48%,
respectively, of total revenues for the three and nine months
ended September 30, 2004.
|
|
(a) |
Guarantees and Financial Instruments with Off-balance
Sheet Risk |
In the normal course of business, the Company is a party to
certain guarantees and financial instruments with off-balance
sheet risk, such as bank letters of credit and performance or
surety bonds. No liabilities related to these arrangements are
reflected in the Companys combined balance sheets.
F-18
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
Management does not expect any material losses to result from
these guarantees or off-balance sheet financial instruments. The
amount of bank letters of credit outstanding as of
September 30, 2005 is $52,966. The amount of surety bonds
currently outstanding related to the Companys reclamation
obligations is presented in note 5 to the condensed
consolidated financial statements. The Company has provided
guarantees for equipment financing obtained by certain of its
contract mining operators totaling approximately $1,150. The
estimated fair value of these guarantees is not significant.
The Company is involved in various legal proceedings from time
to time in the normal course of business. In managements
opinion, the Company is not currently involved in any legal
proceeding which individually or in the aggregate could have a
material effect on the financial condition, results of
operations and/or cash flows of the Company.
In August 2005, as a result of Hurricane Katrina, a portion of
the Companys coal inventory located at a loading facility
in New Orleans was lost or destroyed. During the three months
ended September 30, 2005 the Company wrote down its
inventory based on an estimate of the lost tonnage and recorded
a receivable for the probable related insurance recovery, which
resulted in a net pre-tax charge of $688. The Company expects to
make a final determination of its losses resulting from Katrina
by the end of 2005. It is possible that additional losses will
be recorded; however, the Company does not believe that such
additional losses, if any, will be material.
|
|
(11) |
Discontinued Operations |
On April 14, 2005, the Company sold the assets of its
Colorado mining subsidiary, National King Coal LLC, and related
trucking subsidiary, Gallup Transportation and Transloading
Company, LLC (collectively, NKC), to an unrelated
third party for cash in the amount of $4,400, plus an amount in
cash equal to the fair market value of NKCs coal
inventory, and the assumption by the buyer of certain
liabilities of NKC. The Company recorded a gain on the sale of
NKC of $704 in the second quarter of 2005. The results of
operations of NKC for the current and prior periods have been
reported in discontinued operations. National King Coal LLC was
previously reported in the Coal Operations segment and Gallup
Transportation and Transloading Company, LLC was previously
reported in the All Other segment (note 9).
F-19
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
The following statement of operations data reflects the activity
for the discontinued operation for the three months and nine
months ended September 30, 2005 and 2004:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Nine Months | |
|
|
Ended | |
|
Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
|
|
| |
|
| |
|
| |
Total revenues
|
|
$ |
|
|
|
$ |
5,255 |
|
|
$ |
4,523 |
|
|
$ |
12,756 |
|
Total costs and expenses
|
|
|
|
|
|
|
10,510 |
|
|
|
5,607 |
|
|
|
18,887 |
|
Gain on sale of discontinued operations
|
|
|
|
|
|
|
|
|
|
|
704 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
|
|
|
|
(5,255 |
) |
|
|
(380 |
) |
|
|
(6,131 |
) |
Miscellaneous income
|
|
|
|
|
|
|
7 |
|
|
|
1 |
|
|
|
11 |
|
Income tax benefit from discontinued operations
|
|
|
|
|
|
|
(1,024 |
) |
|
|
(93 |
) |
|
|
(1,120 |
) |
Minority interest in loss from discontinued operations
|
|
|
|
|
|
|
(2,378 |
) |
|
|
(72 |
) |
|
|
(2,773 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
$ |
|
|
|
$ |
(1,846 |
) |
|
$ |
(214 |
) |
|
$ |
(2,227 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Since the condensed consolidated statements of operations for
the nine months ended September 30, 2005 include activity
both prior to and after the Internal Restructuring and initial
public offering, the total income tax provision is the sum of
the provisions for the pre- and post-restructuring periods.
Prior to February 12, 2005, the minority interest owners
and ANR Fund IX Holdings, L.P. owned interests in ANR
Holdings, a limited liability company and pass-through entity
for income tax purposes. As a pass-through entity, ANR Holdings
provides information returns reflecting the allocated income
(loss) to the minority interest owners and ANR Fund IX
Holdings, L.P based upon their respective ownership percentage
and certain special allocations as provided by the limited
liability company agreement and the Internal Revenue Code. The
income tax consequences of the income (loss) allocated to these
owners for the period from January 1, 2005 to
February 11, 2005 and from January 1, 2004 to
September 30, 2004 is not reflected in the financial
statements. For these periods, only the income tax expense
associated with Alpha NR Holding, Inc., a taxable entity, is
included. The primary source of the income tax impact is derived
from the allocated income (loss) from ANR Holdings, Alpha
Natural Resources, LLC and its operating subsidiaries, all of
which are pass-through entities for tax purposes. Subsequent to
the Internal Restructuring and initial public offering, all of
the income of ANR Holdings is taxed to Alpha Natural Resources,
Inc.
A tax provision of $3,542 was recorded for the three months
ended September 30, 2005 on pre-tax income from continuing
operations of $11,752, which equates to an effective tax rate of
30.1%.
A tax provision of $15,141 was recorded for the nine months
ended September 30, 2005 on pre-tax income from continuing
operations of $27,074, which equates to an effective tax rate of
55.9%. This rate is higher than the federal statutory rate of
35% due primarily to the portion of the stock-based compensation
charge associated with the issuance of common stock to
management in connection with the Internal Restructuring and
initial public offering that is not deductible for tax purposes.
The increase in expected income tax expense related to the
stock-based compensation charge is offset in part by the tax
benefits associated with percentage depletion, the
extraterritorial income exclusion, and taxes not being provided
for on the minority interest and pass-through entity
owners respective share of earnings for the period prior
to the restructuring. As $33,029 of the stock-based compensation
charge was identified as a significant unusual item in the first
quarter of 2005, the tax effect of the $33,029 expense (no tax
benefit) was recorded in the first quarter of 2005 and excluded
from the estimated annual effective tax rate of
F-20
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
approximately 27%. The Companys effective tax rate for the
interim periods is applied to pre-tax income exclusive of the
$33,029 stock-based compensation charge.
Significant components of income tax expense from continuing
operations were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
Nine Months Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
Current tax expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$ |
2,149 |
|
|
$ |
944 |
|
|
$ |
10,833 |
|
|
$ |
2,573 |
|
|
State
|
|
|
314 |
|
|
|
18 |
|
|
|
1,629 |
|
|
|
65 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,463 |
|
|
|
962 |
|
|
|
12,462 |
|
|
|
2,638 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred tax expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
868 |
|
|
|
1,113 |
|
|
|
2,155 |
|
|
|
2,437 |
|
|
State
|
|
|
211 |
|
|
|
304 |
|
|
|
524 |
|
|
|
777 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,079 |
|
|
|
1,417 |
|
|
|
2,679 |
|
|
|
3,214 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income tax expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
3,017 |
|
|
|
2,057 |
|
|
|
12,988 |
|
|
|
5,010 |
|
|
State
|
|
|
525 |
|
|
|
322 |
|
|
|
2,153 |
|
|
|
842 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
3,542 |
|
|
$ |
2,379 |
|
|
$ |
15,141 |
|
|
$ |
5,852 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
A reconciliation of the statutory federal income tax expense at
35% to income from continuing operations before income taxes and
minority interest, and the actual income tax expense is as
follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
Nine Months Ended | |
|
|
September 30, | |
|
September 30, | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
|
| |
Federal statutory income tax expense
|
|
$ |
4,114 |
|
|
$ |
6,169 |
|
|
$ |
9,476 |
|
|
$ |
17,260 |
|
Increases (reductions) in taxes due to:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percentage depletion allowance
|
|
|
(1,137 |
) |
|
|
(800 |
) |
|
|
(7,700 |
) |
|
|
(3,005 |
) |
|
Extraterritorial income exclusion
|
|
|
(541 |
) |
|
|
|
|
|
|
(1,246 |
) |
|
|
|
|
|
Deduction for domestic production activities
|
|
|
(68 |
) |
|
|
|
|
|
|
(347 |
) |
|
|
|
|
|
State taxes, net of federal tax impact
|
|
|
342 |
|
|
|
209 |
|
|
|
1,398 |
|
|
|
547 |
|
|
Stock-based compensation
|
|
|
1,031 |
|
|
|
|
|
|
|
14,385 |
|
|
|
|
|
|
Change in valuation allowance
|
|
|
(260 |
) |
|
|
(54 |
) |
|
|
137 |
|
|
|
(203 |
) |
|
Taxes not provided for minority interest
|
|
|
|
|
|
|
(2,572 |
) |
|
|
(1,001 |
) |
|
|
(7,743 |
) |
|
Taxes not provided for pass-through entity
|
|
|
|
|
|
|
(259 |
) |
|
|
(133 |
) |
|
|
(781 |
) |
|
Other, net
|
|
|
61 |
|
|
|
(314 |
) |
|
|
172 |
|
|
|
(223 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Actual income tax expense
|
|
$ |
3,542 |
|
|
$ |
2,379 |
|
|
$ |
15,141 |
|
|
$ |
5,852 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-21
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
Deferred income taxes result from temporary differences between
the reporting of amounts for financial statement purposes and
income tax purposes. The net deferred tax assets and liabilities
included in the condensed consolidated financial statements
include the following amounts:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Deferred tax assets:
|
|
|
|
|
|
|
|
|
|
Investment in limited liability company subsidiary
|
|
$ |
123,696 |
|
|
$ |
|
|
|
Net operating loss carryforwards
|
|
|
2,212 |
|
|
|
5,598 |
|
|
Alternative minimum tax credit carryforward
|
|
|
5,489 |
|
|
|
1,249 |
|
|
Charitable contribution carryforwards
|
|
|
93 |
|
|
|
207 |
|
|
|
|
|
|
|
|
|
|
Gross deferred tax assets
|
|
|
131,490 |
|
|
|
7,054 |
|
|
Less valuation allowance
|
|
|
(108,584 |
) |
|
|
(1,374 |
) |
|
|
|
|
|
|
|
|
|
Total net deferred tax assets
|
|
|
22,906 |
|
|
|
5,680 |
|
|
|
|
|
|
|
|
Deferred tax liabilities:
|
|
|
|
|
|
|
|
|
|
Investment in limited liability company subsidiary
|
|
|
|
|
|
|
(6,869 |
) |
|
Virginia tax credit
|
|
|
(2,889 |
) |
|
|
(1,855 |
) |
|
|
|
|
|
|
|
|
|
Total deferred tax liabilities
|
|
|
(2,889 |
) |
|
|
(8,724 |
) |
|
|
|
|
|
|
|
|
|
|
Net deferred tax asset (liability)
|
|
$ |
20,017 |
|
|
$ |
(3,044 |
) |
|
|
|
|
|
|
|
Changes in the net deferred tax asset (liability) balance
during the nine months ended September 30, 2005 are as
follows:
|
|
|
|
|
ANR Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
Subsidiaries:
|
|
|
|
|
Deferred tax liability balance at December 31, 2004
|
|
$ |
(3,044 |
) |
Deferred tax benefit recorded in period from January 1,
2005 to February 11, 2005 for continuing and discontinued
operations
|
|
|
192 |
|
|
|
|
|
Deferred tax liability balance at February 11, 2005
|
|
$ |
(2,852 |
) |
|
|
|
|
Alpha Natural Resources, Inc.:
|
|
|
|
|
Deferred tax liability balance on February 12, 2005
|
|
$ |
(2,852 |
) |
Estimated deferred tax asset generated from the Internal
Restructuring
|
|
|
132,637 |
|
Valuation allowance established at the time of the Internal
Restructuring
|
|
|
(106,908 |
) |
|
|
|
|
Net deferred taxes recorded as part of Internal Restructuring,
with offsetting increase to additional paid-in capital
|
|
|
25,729 |
|
Deferred tax expense recorded in period from February 12,
2005 to September 30, 2005 for continuing and discontinued
operations
|
|
|
(2,860 |
) |
|
|
|
|
Net deferred tax asset at September 30, 2005
|
|
$ |
20,017 |
|
|
|
|
|
The Internal Restructuring resulted in an increase in the basis
of assets for income tax purposes, currently estimated at
$346,000, which resulted in a gross deferred tax asset of
$132,637. This amount was offset by an increase to the valuation
allowance of $106,908 as of the date of the Internal
Restructuring. The resulting net increase in deferred income
taxes of $25,729 was recorded as an increase to additional
paid-in capital, as the underlying change in the tax basis of
assets of the Company was caused by the Internal Restructuring
transactions between the Company and its stockholders.
F-22
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
Since the Company has not been in business long enough to
develop a strong earnings history (objective evidence as
required by generally accepted accounting principles), and due
to the likelihood that the alternative minimum tax will exceed
the regular tax in the future, the Company has recorded a
valuation allowance of $108,584 as of September 30, 2005.
The Company monitors the valuation allowance each quarter and
makes adjustments to the allowance through the tax provision as
appropriate based primarily upon continued development of an
earnings history and projected future earnings based on future
sales commitments, which impacts the utilization of deferred tax
assets.
The breakdown of the net deferred tax asset (liability), net of
valuation allowance, recorded in the accompanying condensed
consolidated balance sheets is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Current asset
|
|
$ |
401 |
|
|
$ |
4,674 |
|
Current liability
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net current asset
|
|
|
401 |
|
|
|
4,674 |
|
|
|
|
|
|
|
|
Noncurrent asset
|
|
|
22,505 |
|
|
|
1,006 |
|
Noncurrent liability
|
|
|
(2,889 |
) |
|
|
(8,724 |
) |
|
|
|
|
|
|
|
|
Net noncurrent asset (liability)
|
|
|
19,616 |
|
|
|
(7,718 |
) |
|
|
|
|
|
|
|
|
|
Total net deferred tax asset (liability)
|
|
$ |
20,017 |
|
|
$ |
(3,044 |
) |
|
|
|
|
|
|
|
|
|
(13) |
New Accounting Pronouncements |
The FASB issued FIN 47, Accounting for Conditional
Asset Retirement Obligations in March of 2005. FIN 47
clarifies that an entity must record a liability for a
conditional asset retirement obligation if the fair value of the
obligation can be reasonably estimated. This interpretation also
clarifies the circumstances under which an entity would have
sufficient information to reasonably estimate the fair value of
an asset retirement obligation. FIN 47 is effective no
later than the end of fiscal years ending after
December 15, 2005. The Company expects to adopt this
interpretation on December 31, 2005. The Company does not
expect the adoption of this interpretation to have a material
impact on its financial condition, results of operations or cash
flows.
In December 2004, the FASB issued SFAS No. 123(R),
Share-Based Payment, which requires companies to expense
the fair value of equity awards over the required service
period. This Statement is a revision of SFAS No. 123,
Accounting for Stock-Based Compensation.
SFAS No. 123(R) supersedes APB Opinion No. 25,
Accounting for Stock Issued to Employees, which uses the
intrinsic value method to value stock-based compensation. On
April 14, 2005, the SEC adopted a new rule that amends the
effective date of SFAS No. 123(R) to allow SEC
registrants to implement SFAS No. 123(R) as of the
beginning of the first annual reporting period that begins after
June 15, 2005. The Company will adopt
SFAS No. 123(R) effective January 1, 2006.
On October 26, 2005, the Company completed the acquisition
of certain privately held coal reserves and operations in
southern West Virginia and southwestern Virginia (the
Nicewonder Acquisition) for $35,200 in cash,
$221,000 in promissory notes, of which $181,100 was paid on
November 2, 2005 and $39,900 is due on January 15,
2006, and 2,180,233 shares of the Companys common
stock valued at approximately $58,949. The purchase price is
subject to certain post-closing working capital and other
F-23
ALPHA NATURAL RESOURCES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)
adjustments. The Nicewonder Acquisition consisted of the
purchase of the outstanding capital stock of White Flame Energy,
Inc., Twin Star Mining, Inc. and Nicewonder Contracting, Inc.,
the equity interests of Powers Shop, LLC and Buchanan Energy,
LLC and substantially all of the assets of Mate Creek Energy of
W. Va., Inc. and Virginia Energy Company, and the acquisition of
Premium Energy, Inc. by merger (together referred to as the
Nicewonder Coal Group). The operating results of the
Nicewonder Coal Group will be included in the Companys
consolidated results of operations from the date of acquisition.
In connection with the Nicewonder Acquisition, Alpha NR Holding,
Inc. (a wholly-owned subsidiary of Alpha) and its wholly-owned
subsidiary, Alpha Natural Resources, LLC, entered into a senior
secured credit facility with a group of lending institutions led
by Citicorp North America, Inc., as administrative agent (the
New Citicorp Credit Facility). The New Citicorp
Credit Facility consists of a $250,000 term loan facility and a
$275,000 revolving credit facility. The revolving credit
facility includes borrowing capacity available for letters of
credit. Proceeds from the New Citicorp Credit Facility were used
to fund the cash portion of the Nicewonder Acquisition,
including the payment of the first installment on the promissory
notes on November 2, 2005, to refinance the existing
Citicorp Credit Facility (see Note 4) and to pay certain
expenses related to the Nicewonder Acquisition and debt
refinancing. As of November 2, 2005, there were $250,000 in
borrowings under the term loan facility and $40,000 in
borrowings under the revolving credit facility. In addition,
there were $65,487 in letters of credit outstanding, $50,000 of
which resulted from conversion of funded letters of credit that
were outstanding under the existing Citicorp Credit Facility,
and $169,513 was available for borrowing.
Borrowings under the New Citicorp Credit Facility bear interest
at variable rates based upon, at the Companys option,
either the prime rate or a London Interbank Offered Rate, in
each case plus a spread that is generally dependent on a
leverage ratio. The Company will be required to pay a commitment
fee on the unused portion of the revolving credit facility, as
well as customary letter of credit fees. The commitment fee is
initially 0.50% per annum but may be reduced in the future
subject to the attainment of certain leverage ratios. As of
November 2, 2005, the weighted average interest rates
applicable to borrowings under the term loan facility and
revolving credit facility were 5.70% and 6.15%, respectively.
Under the term loan facility, quarterly principal payments of
$625 are required, commencing on March 31, 2006 and ending
on September 30, 2012. The remaining unpaid principal,
which is projected to be $233,125, is due and payable on
October 26, 2012. Any outstanding principal amounts
outstanding under the revolving credit facility are due and
payable on October 26, 2010.
All obligations under the New Citicorp Credit Facility are
unconditionally guaranteed by Alpha NR Holding, Inc. and
each of its existing and future direct and indirect domestic
subsidiaries (other than the borrower, Alpha Natural Resources,
LLC), and are secured by substantially all of the assets of
Alpha NR Holding, Inc. and its subsidiaries. The New Citicorp
Credit Facility contains various affirmative and negative
covenants which, among other things, require the Company to
maintain certain leverage and interest coverage ratios, and
restrict certain payments and transactions, including dividends,
payments for the repurchase of capital stock and mergers or
consolidations.
F-24
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors
Alpha Natural Resources, Inc.:
We have audited the accompanying combined balance sheets of ANR
Fund IX Holdings, L.P. and Alpha NR Holding, Inc. and
subsidiaries (the Company or Successor) as of December 31, 2004
and 2003, and the related combined statements of operations,
stockholders equity and partners capital, and cash
flows for the years ended December 31, 2004 and 2003, and the
period from December 14, 2002 to December 31, 2002 (Successor
Periods), and the combined statements of operations,
shareholders equity, and cash flows for the period from
January 1, 2002 to December 13, 2002 (Predecessor Period).
These combined financial statements are the responsibility of
the Companys management. Our responsibility is to express
an opinion on these combined financial statements based on our
audits.
We conducted our audits in accordance with the standards of the
Public Company Accounting Oversight Board (United States). Those
standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a
reasonable basis of our opinion.
In our opinion, the aforementioned Successor combined financial
statements present fairly, in all material respects, the
financial position of ANR Fund IX Holdings, L.P. and Alpha NR
Holding, Inc. and subsidiaries as of December 31, 2004 and 2003,
and the results of their operations and their cash flows for the
Successor Periods, in conformity with U.S. generally accepted
accounting principles. Further, in our opinion, the
aforementioned Predecessor combined financial statements present
fairly, in all material respects, the results of their
operations and their cash flows for the Predecessor Period, in
conformity with U.S. generally accepted accounting principles.
As discussed in note 1 to the combined financial statements,
effective December 13, 2002, the Company acquired the majority
of the Virginia coal operations of Pittston Coal Company, a
subsidiary of The Brinks Company (formerly known as The
Pittston Company), in a business combination accounted for as a
purchase. As a result of the acquisition, the combined financial
information for the periods after the acquisition is presented
on a different cost basis than that for the periods before the
acquisition and, therefore, is not comparable.
/s/ KPMG LLP
Roanoke, Virginia
March 30, 2005, except as to
notes 1, 22, 28 and 30,
which are as of October 14, 2005
F-25
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
COMBINED BALANCE SHEETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro Forma | |
|
December 31, | |
|
|
December 31, | |
|
| |
|
|
2004 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
(Unaudited) | |
|
|
|
|
|
|
(In thousands) | |
ASSETS |
Current assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
7,391 |
|
|
$ |
7,391 |
|
|
$ |
11,246 |
|
|
Trade accounts receivable, net
|
|
|
95,828 |
|
|
|
95,828 |
|
|
|
70,205 |
|
|
Notes and other receivables
|
|
|
10,835 |
|
|
|
10,835 |
|
|
|
4,742 |
|
|
Inventories
|
|
|
54,569 |
|
|
|
54,569 |
|
|
|
33,113 |
|
|
Due from affiliate
|
|
|
323 |
|
|
|
323 |
|
|
|
3,770 |
|
|
Deferred income taxes
|
|
|
|
|
|
|
4,674 |
|
|
|
489 |
|
|
Prepaid expenses and other current assets
|
|
|
28,915 |
|
|
|
28,915 |
|
|
|
19,256 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
197,861 |
|
|
|
202,535 |
|
|
|
142,821 |
|
Property, plant, and equipment, net
|
|
|
217,964 |
|
|
|
217,964 |
|
|
|
198,147 |
|
Goodwill
|
|
|
18,641 |
|
|
|
18,641 |
|
|
|
17,121 |
|
Other intangibles, net
|
|
|
1,155 |
|
|
|
1,155 |
|
|
|
2,896 |
|
Other assets
|
|
|
36,826 |
|
|
|
36,826 |
|
|
|
18,351 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
472,447 |
|
|
$ |
477,121 |
|
|
$ |
379,336 |
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY (DEFICIT) AND
PARTNERS CAPITAL |
Current liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current portion of long-term debt
|
|
$ |
1,693 |
|
|
$ |
1,693 |
|
|
$ |
13,329 |
|
|
Note payable
|
|
|
15,228 |
|
|
|
15,228 |
|
|
|
14,425 |
|
|
Notes payable to affiliates
|
|
|
517,692 |
|
|
|
|
|
|
|
|
|
|
Bank overdraft
|
|
|
10,024 |
|
|
|
10,024 |
|
|
|
5,854 |
|
|
Trade accounts payable
|
|
|
51,050 |
|
|
|
51,050 |
|
|
|
41,357 |
|
|
Accrued expenses and other current liabilities
|
|
|
68,283 |
|
|
|
68,283 |
|
|
|
35,142 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
663,970 |
|
|
|
146,278 |
|
|
|
110,107 |
|
Long-term debt, net of current portion
|
|
|
184,784 |
|
|
|
184,784 |
|
|
|
57,210 |
|
Workers compensation benefits
|
|
|
4,678 |
|
|
|
4,678 |
|
|
|
1,660 |
|
Postretirement medical benefits
|
|
|
15,637 |
|
|
|
15,637 |
|
|
|
10,662 |
|
Asset retirement obligation
|
|
|
32,888 |
|
|
|
32,888 |
|
|
|
32,607 |
|
Deferred gains on sale of property interests
|
|
|
5,516 |
|
|
|
5,516 |
|
|
|
6,934 |
|
Deferred income taxes
|
|
|
|
|
|
|
7,718 |
|
|
|
823 |
|
Other liabilities
|
|
|
15,411 |
|
|
|
4,911 |
|
|
|
6,486 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
922,884 |
|
|
|
402,410 |
|
|
|
226,489 |
|
|
|
|
|
|
|
|
|
|
|
Minority interest
|
|
|
|
|
|
|
28,778 |
|
|
|
66,480 |
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity (deficit) and partners
capital:
|
|
|
|
|
|
|
|
|
|
|
|
|
Alpha Natural Resources, Inc.:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock par value $0.01,
10,000,000 shares authorized, none issued
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock par value $0.01,
100,000,000 shares authorized, 28,287,580 shares
issued and outstanding
|
|
|
283 |
|
|
|
|
|
|
|
|
|
|
Deficit capital
|
|
|
(450,720 |
) |
|
|
|
|
|
|
|
|
|
Retained earnings
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Alpha Natural Resources, Inc. stockholders (deficit)
|
|
|
(450,437 |
) |
|
|
|
|
|
|
|
|
Alpha NR Holding, Inc.:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock par value $0.01, 1,000 shares
authorized, none issued
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock par value $0.01, 1,000 shares
authorized, 100 shares issued and outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additional paid-in capital
|
|
|
|
|
|
|
22,153 |
|
|
|
75,710 |
|
|
Retained earnings
|
|
|
|
|
|
|
18,828 |
|
|
|
1,442 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Alpha NR Holding, Inc. stockholders equity
|
|
|
|
|
|
|
40,981 |
|
|
|
77,152 |
|
Alpha Fund IX Holdings, L.P.:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Partners capital
|
|
|
|
|
|
|
4,952 |
|
|
|
9,215 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity (deficit) and
partners capital
|
|
|
(450,437 |
) |
|
|
45,933 |
|
|
|
86,367 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
(deficit) and partners capital
|
|
$ |
472,447 |
|
|
$ |
477,121 |
|
|
$ |
379,336 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-26
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
COMBINED STATEMENTS OF OPERATIONS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Company | |
|
|
Predecessor | |
|
|
| |
|
|
| |
|
|
|
|
Period from | |
|
|
Period from | |
|
|
Year Ended | |
|
December 14, | |
|
|
January 1, | |
|
|
December 31, | |
|
2002 to | |
|
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
December 13, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
2002 | |
|
|
| |
|
| |
|
| |
|
|
| |
|
|
(In thousands) | |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
1,079,733 |
|
|
$ |
694,591 |
|
|
$ |
6,260 |
|
|
|
$ |
154,715 |
|
|
Freight and handling revenues
|
|
|
141,100 |
|
|
|
73,800 |
|
|
|
1,009 |
|
|
|
|
17,001 |
|
|
Other revenues
|
|
|
31,869 |
|
|
|
13,458 |
|
|
|
101 |
|
|
|
|
6,031 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
1,252,702 |
|
|
|
781,849 |
|
|
|
7,370 |
|
|
|
|
177,747 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal sales (exclusive of items shown separately below)
|
|
|
920,359 |
|
|
|
626,265 |
|
|
|
6,268 |
|
|
|
|
158,924 |
|
|
Freight and handling costs
|
|
|
141,100 |
|
|
|
73,800 |
|
|
|
1,009 |
|
|
|
|
17,001 |
|
|
Cost of other revenues
|
|
|
22,994 |
|
|
|
12,488 |
|
|
|
120 |
|
|
|
|
7,973 |
|
|
Depreciation, depletion and amortization
|
|
|
55,261 |
|
|
|
35,385 |
|
|
|
274 |
|
|
|
|
6,814 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
43,881 |
|
|
|
21,926 |
|
|
|
471 |
|
|
|
|
8,797 |
|
|
Costs to exit business
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
25,274 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
1,183,595 |
|
|
|
769,864 |
|
|
|
8,142 |
|
|
|
|
224,783 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refund of federal black lung excise tax
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,049 |
|
Other operating income, net
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,430 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
69,107 |
|
|
|
11,985 |
|
|
|
(772 |
) |
|
|
|
(43,557 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(20,041 |
) |
|
|
(7,848 |
) |
|
|
(203 |
) |
|
|
|
(35 |
) |
|
Interest income
|
|
|
531 |
|
|
|
103 |
|
|
|
6 |
|
|
|
|
2,072 |
|
|
Miscellaneous income
|
|
|
722 |
|
|
|
574 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense), net
|
|
|
(18,788 |
) |
|
|
(7,171 |
) |
|
|
(197 |
) |
|
|
|
2,037 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations before income taxes and
minority interest
|
|
|
50,319 |
|
|
|
4,814 |
|
|
|
(969 |
) |
|
|
|
(41,520 |
) |
Income tax expense (benefit)
|
|
|
5,150 |
|
|
|
898 |
|
|
|
(334 |
) |
|
|
|
(17,198 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before minority interest
|
|
|
45,169 |
|
|
|
3,916 |
|
|
|
(635 |
) |
|
|
|
(24,322 |
) |
Minority interest
|
|
|
22,781 |
|
|
|
1,164 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
22,388 |
|
|
|
2,752 |
|
|
|
(635 |
) |
|
|
|
(24,322 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discontinued operations (note 30):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations before income taxes and
minority interest
|
|
|
(6,514 |
) |
|
|
(950 |
) |
|
|
|
|
|
|
|
|
|
Income tax benefit
|
|
|
(1,190 |
) |
|
|
(230 |
) |
|
|
|
|
|
|
|
|
|
Minority interest
|
|
|
(2,951 |
) |
|
|
(230 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
|
(2,373 |
) |
|
|
(490 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
20,015 |
|
|
$ |
2,262 |
|
|
$ |
(635 |
) |
|
|
$ |
(24,322 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-27
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
COMBINED STATEMENTS OF STOCKHOLDERS EQUITY AND
PARTNERS CAPITAL
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retained |
|
|
|
Net | |
|
Deferred | |
|
|
|
|
|
|
Earnings |
|
|
|
Receivables | |
|
Taxes | |
|
|
|
|
Capital |
|
(Accumulated |
|
Company | |
|
from | |
|
Receivable | |
|
|
Predecessor |
|
Contributions |
|
Deficit) |
|
Equity | |
|
Affiliates | |
|
from Parent | |
|
Total | |
|
|
|
|
|
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands) | |
Balances, December 31, 2001
|
|
$ |
|
|
|
$ |
|
|
|
$ |
211,313 |
|
|
$ |
(279,374 |
) |
|
$ |
(68,532 |
) |
|
$ |
(136,593 |
) |
|
Net loss
|
|
|
|
|
|
|
|
|
|
|
(24,322 |
) |
|
|
|
|
|
|
|
|
|
|
(24,322 |
) |
|
Capital contribution
|
|
|
|
|
|
|
|
|
|
|
329,964 |
|
|
|
(329,964 |
) |
|
|
|
|
|
|
|
|
|
Affiliate transactions, net
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
35,937 |
|
|
|
|
|
|
|
35,937 |
|
|
Deferred taxes receivable from parent
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(8,023 |
) |
|
|
(8,023 |
) |
|
Other
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4 |
|
|
|
4 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 13, 2002
|
|
$ |
|
|
|
$ |
|
|
|
$ |
516,955 |
|
|
$ |
(573,401 |
) |
|
$ |
(76,551 |
) |
|
$ |
(132,997 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total | |
|
|
|
Total | |
|
|
|
|
|
|
Retained | |
|
Alpha NR | |
|
|
|
Stockholders | |
|
|
|
|
Additional | |
|
Earnings | |
|
Holding, Inc. | |
|
|
|
Equity and | |
|
|
Common |
|
Paid-In | |
|
(Accumulated | |
|
Stockholders | |
|
Partners | |
|
Partners | |
Company |
|
Stock |
|
Capital | |
|
Deficit) | |
|
Equity | |
|
Capital | |
|
Capital | |
|
|
|
|
| |
|
| |
|
| |
|
| |
|
| |
Balances, December 14, 2002
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
Net loss
|
|
|
|
|
|
|
|
|
|
|
(529 |
) |
|
|
(529 |
) |
|
|
(106 |
) |
|
|
(635 |
) |
|
Contributed capital
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,635 |
|
|
|
2,635 |
|
|
Issuance of common stock
|
|
|
|
|
|
|
21,384 |
|
|
|
|
|
|
|
21,384 |
|
|
|
|
|
|
|
21,384 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2002
|
|
|
|
|
|
|
21,384 |
|
|
|
(529 |
) |
|
|
20,855 |
|
|
|
2,529 |
|
|
|
23,384 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
1,971 |
|
|
|
1,971 |
|
|
|
291 |
|
|
|
2,262 |
|
|
Contributed capital
|
|
|
|
|
|
|
15,153 |
|
|
|
|
|
|
|
15,153 |
|
|
|
1,868 |
|
|
|
17,021 |
|
|
Notes payable to affiliate contributed to capital
|
|
|
|
|
|
|
39,173 |
|
|
|
|
|
|
|
39,173 |
|
|
|
4,827 |
|
|
|
44,000 |
|
|
Noncash distribution of Virginia Tax Credit
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(300 |
) |
|
|
(300 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2003
|
|
|
|
|
|
|
75,710 |
|
|
|
1,442 |
|
|
|
77,152 |
|
|
|
9,215 |
|
|
|
86,367 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
17,386 |
|
|
|
17,386 |
|
|
|
2,629 |
|
|
|
20,015 |
|
|
Noncash distribution of Virginia Tax Credit
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(292 |
) |
|
|
(292 |
) |
|
Distributions
|
|
|
|
|
|
|
(53,557 |
) |
|
|
|
|
|
|
(53,557 |
) |
|
|
(6,600 |
) |
|
|
(60,157 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2004
|
|
$ |
|
|
|
$ |
22,153 |
|
|
$ |
18,828 |
|
|
$ |
40,981 |
|
|
$ |
4,952 |
|
|
$ |
45,933 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-28
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
COMBINED STATEMENTS OF CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Company | |
|
|
Predecessor | |
|
|
| |
|
|
| |
|
|
|
|
Period from | |
|
|
Period from | |
|
|
|
|
December 14, | |
|
|
January 1, | |
|
|
Year Ended December 31, | |
|
2002 to | |
|
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
December 13, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
2002 | |
|
|
| |
|
| |
|
| |
|
|
| |
|
|
(In thousands) | |
Operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
20,015 |
|
|
$ |
2,262 |
|
|
$ |
(635 |
) |
|
|
$ |
(24,322 |
) |
|
Adjustments to reconcile net income (loss) to net cash provided
by (used in) operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
56,012 |
|
|
|
36,054 |
|
|
|
274 |
|
|
|
|
6,814 |
|
|
|
Amortization and write-off of debt issuance costs
|
|
|
4,474 |
|
|
|
1,276 |
|
|
|
59 |
|
|
|
|
|
|
|
|
Minority interest
|
|
|
19,830 |
|
|
|
934 |
|
|
|
|
|
|
|
|
|
|
|
|
Accretion of asset retirement obligation
|
|
|
3,301 |
|
|
|
2,699 |
|
|
|
57 |
|
|
|
|
|
|
|
|
Virginia tax credit
|
|
|
(4,872 |
) |
|
|
(4,313 |
) |
|
|
|
|
|
|
|
|
|
|
|
Stock-based compensation
|
|
|
91 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Bad debt provision
|
|
|
152 |
|
|
|
68 |
|
|
|
5 |
|
|
|
|
1,296 |
|
|
|
Net pension credit
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(928 |
) |
|
|
Loss on settlement of asset retirement obligation
|
|
|
762 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset impairment charge
|
|
|
5,100 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for non-recoupable advance mining royalties
|
|
|
758 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of deferred gains on sales of property interests
|
|
|
(959 |
) |
|
|
(618 |
) |
|
|
|
|
|
|
|
|
|
|
|
Gain on sale of fixed assets, net
|
|
|
(671 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
2,711 |
|
|
|
668 |
|
|
|
(334 |
) |
|
|
|
(8,023 |
) |
|
|
Other, net
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
11 |
|
|
|
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Trade accounts receivable
|
|
|
(25,775 |
) |
|
|
(21,056 |
) |
|
|
(7,472 |
) |
|
|
|
5,244 |
|
|
|
|
Notes and other receivables
|
|
|
(1,062 |
) |
|
|
(2,358 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Inventories
|
|
|
(21,040 |
) |
|
|
13,014 |
|
|
|
549 |
|
|
|
|
|
|
|
|
|
Prepaid expenses and other current assets
|
|
|
5,568 |
|
|
|
793 |
|
|
|
(138 |
) |
|
|
|
(5,418 |
) |
|
|
|
Other assets
|
|
|
805 |
|
|
|
(3,051 |
) |
|
|
|
|
|
|
|
(1,850 |
) |
|
|
|
Trade accounts payable
|
|
|
9,742 |
|
|
|
12,234 |
|
|
|
4,057 |
|
|
|
|
(3,925 |
) |
|
|
|
Accrued expenses and other current liabilities
|
|
|
27,243 |
|
|
|
16,392 |
|
|
|
4,706 |
|
|
|
|
(15,115 |
) |
|
|
|
Workers compensation benefits
|
|
|
3,018 |
|
|
|
1,660 |
|
|
|
|
|
|
|
|
1,879 |
|
|
|
|
Postretirement medical benefits
|
|
|
4,975 |
|
|
|
1,236 |
|
|
|
36 |
|
|
|
|
6,710 |
|
|
|
|
Asset retirement obligation expenditures
|
|
|
(3,306 |
) |
|
|
(2,252 |
) |
|
|
|
|
|
|
|
(1,270 |
) |
|
|
|
Other liabilities
|
|
|
(96 |
) |
|
|
(1,538 |
) |
|
|
(1,459 |
) |
|
|
|
25,081 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) operating activities
|
|
$ |
106,776 |
|
|
$ |
54,104 |
|
|
$ |
(295 |
) |
|
|
$ |
(13,816 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-29
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
COMBINED STATEMENTS OF CASH FLOWS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Company | |
|
|
Predecessor | |
|
|
| |
|
|
| |
|
|
|
|
Period from | |
|
|
Period from | |
|
|
|
|
December 14, | |
|
|
January 1, | |
|
|
Year Ended December 31, | |
|
2002 to | |
|
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
December 13, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
2002 | |
|
|
| |
|
| |
|
| |
|
|
| |
|
|
(In thousands) | |
Investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures
|
|
$ |
(72,046 |
) |
|
$ |
(27,719 |
) |
|
$ |
(960 |
) |
|
|
$ |
(21,866 |
) |
|
Proceeds from disposition of property, plant, and equipment
|
|
|
1,096 |
|
|
|
65,174 |
|
|
|
|
|
|
|
|
76 |
|
|
Purchase of net assets of acquired companies
|
|
|
(2,891 |
) |
|
|
(133,757 |
) |
|
|
(37,202 |
) |
|
|
|
|
|
|
Purchase of equity investment
|
|
|
(4,500 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Issuance of note receivable to coal supplier, net of collections
of $1,519
|
|
|
(8,481 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred acquisition costs
|
|
|
|
|
|
|
|
|
|
|
(731 |
) |
|
|
|
|
|
|
Decrease (increase) in due from affiliate
|
|
|
620 |
|
|
|
(3,770 |
) |
|
|
|
|
|
|
|
|
|
|
Other, net
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(264 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(86,202 |
) |
|
|
(100,072 |
) |
|
|
(38,893 |
) |
|
|
|
(22,054 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Repayments of notes payable
|
|
|
(14,425 |
) |
|
|
(15,600 |
) |
|
|
|
|
|
|
|
|
|
|
Proceeds from issuance of long-term debt
|
|
|
175,000 |
|
|
|
58,518 |
|
|
|
|
|
|
|
|
|
|
|
Repayments on long-term debt
|
|
|
(61,422 |
) |
|
|
(30,054 |
) |
|
|
|
|
|
|
|
|
|
|
Increase in bank overdraft
|
|
|
4,170 |
|
|
|
5,854 |
|
|
|
|
|
|
|
|
|
|
|
Debt issuance costs
|
|
|
(10,525 |
) |
|
|
(5,181 |
) |
|
|
(340 |
) |
|
|
|
|
|
|
Deferred common stock offering costs
|
|
|
(1,655 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Advances from affiliates
|
|
|
|
|
|
|
20,047 |
|
|
|
23,953 |
|
|
|
|
35,783 |
|
|
Capital contributions
|
|
|
|
|
|
|
3,118 |
|
|
|
2,635 |
|
|
|
|
|
|
|
Issuance of common stock
|
|
|
|
|
|
|
15,153 |
|
|
|
21,384 |
|
|
|
|
|
|
|
Distributions to owners
|
|
|
(60,156 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributions to minority interest
|
|
|
(55,416 |
) |
|
|
(3,085 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities
|
|
|
(24,429 |
) |
|
|
48,770 |
|
|
|
47,632 |
|
|
|
|
35,783 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and cash equivalents
|
|
|
(3,855 |
) |
|
|
2,802 |
|
|
|
8,444 |
|
|
|
|
(87 |
) |
Cash and cash equivalents at beginning of period
|
|
|
11,246 |
|
|
|
8,444 |
|
|
|
|
|
|
|
|
175 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$ |
7,391 |
|
|
$ |
11,246 |
|
|
$ |
8,444 |
|
|
|
$ |
88 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-30
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL STATEMENTS
(In thousands, except percentages and share data)
|
|
(1) |
Business and Basis of Presentation |
|
|
|
Organization and Business |
ANR Fund IX Holdings, L.P. and Alpha NR Holding, Inc.,
formerly named Alpha Natural Resources, Inc., (together, the FR
Affiliates) are entities under the common control of First
Reserve GP IX, Inc. and were formed in 2002 to acquire coal
mining assets in the Appalachian region of the United States. In
December 2002, ANR Fund IX Holdings, L.P. and Alpha NR
Holding, Inc. formed ANR Holdings, LLC (ANR Holdings) and
acquired membership interests of approximately 11% and 89%,
respectively. ANR Holdings is the parent of Alpha Natural
Resources, LLC (Alpha) and the latter entity and its
subsidiaries acquired our Predecessor, the majority of the
Virginia coal operations of Pittston Coal Company, a subsidiary
of The Brinks Company (formerly known as The Pittston
Company), on December 13, 2002 (described in note 20).
The acquisition of Coastal Coal Company (described in
note 20) was completed on January 31, 2003 by
subsidiaries of ANR Holdings. The acquisition of U.S. AMCI
(described in note 20) was completed on March 11,
2003. Concurrent with the acquisition of U.S. AMCI, ANR
Holdings issued additional membership interests in the aggregate
amount of 45.3% to the former owners of U.S. AMCI, Madison
Capital Funding, LLC and members of management in exchange for
the net assets of U.S. AMCI and cash. After completion of
this transaction, the FR Affiliates owned 54.7% of ANR Holdings.
The acquisition of Mears Enterprises, Inc. and affiliated
entities (described in note 20) was completed on
November 17, 2003.
The financial statements for the period from December 14,
2002 to December 31, 2002, and the years ended
December 31, 2003 and 2004 are presented on a combined
basis. The entities included in the combined financial
statements, except our Predecessor, are collectively referred to
as the Company.
The Company and its operating subsidiaries are engaged in the
business of extracting, processing and marketing coal from deep
and surface mines, principally located in the Eastern and
Southeastern regions of the United States, for sale to utility
and steel companies in the United States and in international
markets.
|
|
|
Operating Subsidiaries of Alpha Natural Resources,
LLC |
Companies with coal reserves and/or production facilities:
|
|
|
|
|
Paramont Coal Company Virginia, LLC |
|
|
|
Dickenson-Russell Coal Company, LLC |
|
|
|
Alpha Terminal Company, LLC |
|
|
|
Alpha Land and Reserves, LLC |
|
|
|
AMFIRE, LLC and Subsidiaries |
|
|
|
McDowell-Wyoming Coal Company, LLC and Subsidiaries |
Companies providing administrative, sales and other services:
|
|
|
|
|
Alpha Coal Sales Co., LLC |
|
|
|
Alpha Natural Resources Capital Corp. |
|
|
|
Alpha Natural Resources Services, LLC |
F-31
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
Maxxim Rebuild Co., LLC |
|
|
|
Maxxim Shared Services, LLC |
Holding companies:
|
|
|
|
|
Maxxum Carbon Resources, LLC |
|
|
|
Esperanza Coal Co., LLC |
|
|
|
Principles of Combination |
The accompanying combined financial statements include the
accounts of the Company described above. All significant
intercompany accounts and transactions have been eliminated.
Prior to December 13, 2002, the Company had no operations.
On December 13, 2002, the Company acquired the majority of
the Virginia coal operations of Pittston Coal Company (the
Combined Virginia Entity or Predecessor) through a number of
asset acquisitions by the Companys subsidiaries. The
Combined Virginia Entity is considered the Predecessor to the
Company. As such, the historical financial statements of the
Combined Virginia Entity are included in the accompanying
combined financial statements, including the combined statements
of operations, cash flows, and shareholders equity, for
the period from January 1, 2002 to December 13, 2002
(the Predecessor combined financial statements). The
Predecessor combined financial statements are not necessarily
indicative of the future financial position or results of
operations of the Company.
The Predecessors combined financial statements have not
been adjusted to give effect to the acquisition. For this
reason, the combined financial statements of the Company after
the acquisition are not comparable to the Predecessors
combined financial statements prior to the acquisition.
The accompanying combined balance sheets as of December 31,
2004 and 2003, and the combined statements of operations, cash
flows, and stockholders equity and partners capital
for the years ended December 31, 2004 and 2003 and the
period from December 14, 2002 to December 31, 2002,
reflect the combined financial position, results of operations
and cash flows of the Company from the date of acquisition of
the Predecessor. See also note 20.
On April 14, 2005, the Company sold the assets of its
Colorado mining subsidiary, National King Coal LLC, and related
trucking subsidiary, Gallup Transportation and Transloading
Company, LLC (collectively NKC) to an unrelated
third party. The results of operations of NKC for the years
ended December 31, 2004 and 2003 have been reported in
discontinued operations. See also note 30.
|
|
|
Subsequent Internal Restructuring and Initial Public
Offering |
On February 11, 2005, the Company completed a series of
transactions to transition from a structure in which the
Companys top-tier holding company was a limited liability
company, ANR Holdings, to one in which the top-tier holding
company is a corporation, Alpha Natural Resources, Inc., which
was formed on November 29, 2004. These transactions are
referred to collectively as the Internal Restructuring, and they
included the following:
|
|
|
|
|
Alpha Coal Management, LLC (ACM) was dissolved and
liquidated, after which (1) the interests in ANR Holdings
previously held by ACM were distributed to and held directly by
the Companys officers and employees who were owners of ACM
prior to its dissolution and (2) outstanding |
F-32
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
options to purchase units in ACM were automatically converted
into options to purchase up to 596,985 shares of Alpha
Natural Resources, Inc. common stock at an exercise price of
$12.73 per share, and Alpha Natural Resources, Inc. assumed
the obligations of ACM under the Alpha Coal Management, LLC 2004
Long-Term Incentive Plan. |
|
|
|
Alpha Natural Resources, Inc. assumed the obligations of ANR
Holdings to make distributions to (1) affiliates of AMCI in
an aggregate amount of $6,000, representing the approximate
incremental tax resulting from the recognition of additional tax
liability resulting from the Internal Restructuring and
(2) First Reserve Fund IX, L.P. in an aggregate amount
of approximately $4,500, representing the approximate value of
tax attributes conveyed as a result of the Internal
Restructuring (collectively, the Sponsor Distributions). The
Sponsor Distributions to affiliates of AMCI are payable in five
equal installments on the dates for which estimated income tax
payments are due in each of April 2005, June 2005, September
2005, January 2006 and April 2006. The Sponsor Distributions to
First Reserve Fund IX, L.P. are payable in three
installments of approximately $2,100, $2,100 and $300 on
December 15, 2007, 2008 and 2009, respectively. The Sponsor
Distributions will be payable in cash or, to the extent Alpha
Natural Resources, Inc. is not permitted by the terms of the
senior credit facility or the indenture governing the senior
notes to pay the Sponsor Distributions in cash, in shares of
Alpha Natural Resources, Inc. common stock. |
|
|
|
First Reserve Fund IX, L.P., the direct parent of Alpha NR
Holding, Inc., contributed all of the outstanding common stock
of Alpha NR Holding, Inc. to Alpha Natural Resources, Inc. in
exchange for 12,462,992 shares of Alpha Natural Resources,
Inc. common stock and demand promissory notes in an aggregate
adjusted principal amount of $206,734. |
|
|
|
ANR Fund IX Holdings, L.P., Madison Capital Funding, LLC
and affiliates of AMCI contributed all of their membership
interests in ANR Holdings to Alpha Natural Resources, Inc. in
exchange for 13,052,431 shares of Alpha Natural Resources,
Inc. common stock and demand promissory notes in an aggregate
adjusted principal amount of $310,958. |
|
|
|
The officers and employees who were the members of ACM
contributed all of their interests in ANR Holdings to Alpha
Natural Resources, Inc. in exchange for 2,772,157 shares of
Alpha Natural Resources, Inc. common stock. |
|
|
|
The Board of Directors of Alpha Natural Resources, Inc. declared
a pro rata distribution to the former members of ANR Holdings in
an aggregate amount equal to the net proceeds Alpha Natural
Resources, Inc. received upon the exercise by the underwriters
of their over-allotment option with respect to the public
offering described below. |
|
|
|
Alpha Natural Resources, Inc. recorded a change of $3,044 in net
deferred income taxes (an estimated increase of $100,600 in
gross deferred tax assets, less an estimated increase of $97,556
in the valuation allowance for deferred tax assets) recognized
upon the completion of the Internal Restructuring. |
|
|
|
The Company, the FR Affiliates and affiliates of AMCI amended
certain of the post-closing arrangements previously entered into
as part of the Companys acquisition of U.S. AMCI. |
|
|
|
Alpha Natural Resources, Inc. contributed the membership
interests in ANR Holdings received in the Internal Restructuring
to Alpha NR Holding, Inc. and another indirect wholly-owned
subsidiary of Alpha Natural Resources, Inc. |
The accompanying unaudited pro forma balance sheet data as of
December 31, 2004 gives effect to the Internal
Restructuring described above as if it had occurred on
December 31, 2004.
F-33
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The following unaudited pro forma statement of operations data
for the years ended December 31, 2004 and 2003 give effect
to the Internal Restructuring described above, the issuance of
$175,000 principal amount of 10% senior notes due 2012 by
our subsidiaries Alpha Natural Resources, LLC and Alpha Natural
Resources Capital Corp. and the entry by Alpha Natural
Resources, LLC into a $175,000 credit facility in May 2004 (see
note 12), which we refer to as the 2004 Financings, and the
2003 Acquisitions (see note 20), as if the Internal
Restructuring, 2004 Financings, and 2003 Acquisitions had
occurred on January 1, 2003. This pro forma data is for
informational purposes only, and should not be considered
indicative of results that would have been achieved had the
transactions listed above actually been consummated on
January 1, 2003:
|
|
|
|
|
|
|
Year Ended December 31, |
|
|
|
|
|
2004 |
|
2003 |
|
|
|
|
|
Pro forma revenues
|
|
$1,269,718 |
|
$902,766 |
Pro forma net income
|
|
29,637 |
|
536 |
The following unaudited table reconciles reported net income to
pro forma net income as if the Internal Restructuring, 2004
Financings, and 2003 Acquisitions had occurred on
January 1, 2003:
|
|
|
|
|
|
|
|
|
|
|
Year Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Reported income from continuing operations
|
|
$ |
22,388 |
|
|
$ |
2,752 |
|
Add: Pro forma results of operations related to the 2003
Acquisitions, net of income taxes
|
|
|
|
|
|
|
3,507 |
|
Deduct: Income tax effect of ANR Fund IX Holdings, L.P.
income from continuing operations prior to Internal Restructuring
|
|
|
(1,149 |
) |
|
|
(138 |
) |
Deduct: Pro forma effects of the 2004 Financings, net of income
taxes
|
|
|
(1,672 |
) |
|
|
(7,728 |
) |
Add: Elimination of minority interest in income from continuing
operations, net of income tax effects of Internal Restructuring
|
|
|
14,124 |
|
|
|
2,822 |
|
|
|
|
|
|
|
|
Pro forma income from continuing operations
|
|
|
33,691 |
|
|
|
1,215 |
|
|
|
|
|
|
|
|
Reported loss from discontinued operations
|
|
|
(2,373 |
) |
|
|
(490 |
) |
Add: Income tax effect of ANR Fund IX Holdings, L.P. loss
from discontinued operations prior to Internal Restructuring
|
|
|
149 |
|
|
|
27 |
|
Deduct: Elimination of minority interest in loss from
discontinued operations, net of income tax effects of Internal
Restructuring
|
|
|
(1,830 |
) |
|
|
(216 |
) |
|
|
|
|
|
|
|
Pro forma loss from discontinued operations
|
|
|
(4,054 |
) |
|
|
(679 |
) |
|
|
|
|
|
|
|
Pro forma net income
|
|
$ |
29,637 |
|
|
$ |
536 |
|
|
|
|
|
|
|
|
F-34
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The following unaudited pro forma earnings per share data for
the years ended December 31, 2004 and 2003 give effect to
the Internal Restructuring, the 2004 Financings, and the 2003
Acquisitions as if these transactions had occurred on
January 1, 2003:
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Pro forma earnings per share data:
|
|
|
|
|
|
|
|
|
Net income per basic share:
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
1.25 |
|
|
$ |
0.05 |
|
|
Loss from discontinued operations
|
|
$ |
(0.15 |
) |
|
$ |
(0.03 |
) |
|
Net income per basic share
|
|
$ |
1.10 |
|
|
$ |
0.02 |
|
Shares outstanding basic
|
|
|
26,942,650 |
|
|
|
26,942,650 |
|
Net income per diluted share:
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
1.18 |
|
|
$ |
0.04 |
|
|
Loss from discontinued operations
|
|
$ |
(0.14 |
) |
|
$ |
(0.02 |
) |
|
Net income per basic share
|
|
$ |
1.04 |
|
|
$ |
0.02 |
|
Shares outstanding diluted
|
|
|
28,484,586 |
|
|
|
28,484,586 |
|
On February 18, 2005, Alpha Natural Resources, Inc.
completed the initial public offering of 33,925,000 shares
of its common stock, including 4,425,000 shares issued
pursuant to the exercise in full of the underwriters
over-allotment option. Alpha Natural Resources, Inc. received
net proceeds (after deducting issuance costs) of $596,592 from
the offering. Alpha Natural Resources, Inc. used $517,982 of the
net proceeds to repay all outstanding principal and accrued
interest on its demand promissory notes issued in the Internal
Restructuring to the FR Affiliates, affiliates of AMCI and
Madison Capital Funding LLC, and the remaining $78,610 of the
net proceeds were distributed by Alpha Natural Resources, Inc.
on a pro rata basis to its stockholders of record as of the
close of business on February 11, 2005 pursuant to the
distribution declared by Alpha Natural Resources, Inc.s
Board of Directors in connection with the Internal Restructuring.
At December 31, 2004, included in other assets are deferred
costs related to the initial public offering in the amount of
$3,665. These deferred costs will be charged against the
proceeds of the public offering.
F-35
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The following unaudited pro forma, as adjusted, earnings per
share data for the years ended December 31, 2004 and 2003
give effect to the Internal Restructuring, the 2004 Financings,
the 2003 Acquisitions, and our initial public offering of common
stock completed on February 18, 2005 as if these
transactions had occurred on January 1, 2003:
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Pro forma, as adjusted, earnings per share data:
|
|
|
|
|
|
|
|
|
Net income per basic share:
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.55 |
|
|
$ |
0.02 |
|
|
Loss from discontinued operations
|
|
$ |
(0.06 |
) |
|
$ |
(0.01 |
) |
|
Net income per basic share
|
|
$ |
0.49 |
|
|
$ |
0.01 |
|
Shares outstanding basic
|
|
|
60,867,650 |
|
|
|
60,867,650 |
|
Net income per diluted share:
|
|
|
|
|
|
|
|
|
|
Income from continuing operations
|
|
$ |
0.54 |
|
|
$ |
0.02 |
|
|
Loss from discontinued operations
|
|
$ |
(0.07 |
) |
|
$ |
(0.01 |
) |
|
Net income per basic share
|
|
$ |
0.47 |
|
|
$ |
0.01 |
|
Shares outstanding diluted
|
|
|
62,409,586 |
|
|
|
62,409,586 |
|
|
|
(2) |
Summary of Significant Accounting Policies and Practices |
|
|
(a) |
Cash and Cash Equivalents |
Cash and cash equivalents consist of cash and highly liquid,
short-term investments. Cash and cash equivalents are stated at
cost, which approximates fair market value. For purposes of the
combined statements of cash flows, the Company considers all
highly liquid debt instruments with original maturities of three
months or less to be cash equivalents.
|
|
(b) |
Trade Accounts Receivable and Allowance for Doubtful
Accounts |
Trade accounts receivable are recorded at the invoiced amount
and do not bear interest. The allowance for doubtful accounts is
the Companys best estimate of the amount of probable
credit losses in the Companys existing accounts
receivable. The Company establishes provisions for losses on
accounts receivable when it is probable that all or part of the
outstanding balance will not be collected. The Company regularly
reviews collectibility and establishes or adjusts the allowance
as necessary using the specific identification method. Account
balances are charged off against the allowance after all means
of collection have been exhausted and the potential for recovery
is considered remote. The Company does not have any
off-balance-sheet credit exposure related to its customers.
The changes in the allowance for doubtful accounts were as
follows:
|
|
|
|
|
Bad debt provision
|
|
$ |
5 |
|
|
|
|
|
Balance as of December 31, 2002
|
|
|
5 |
|
Bad debt provision
|
|
|
68 |
|
|
|
|
|
Balance as of December 31, 2003
|
|
|
73 |
|
Bad debt provision
|
|
|
152 |
|
Bad debt write-offs
|
|
|
(132 |
) |
|
|
|
|
Balance as of December 31, 2004
|
|
$ |
93 |
|
|
|
|
|
F-36
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Coal inventories are stated at the lower of cost or market. The
cost of coal inventories is determined based on average cost of
production, which includes all costs incurred to extract,
transport and process the coal. Coal is classified as inventory
at the point in time the coal is extracted from the mine and
weighed at a loading facility.
Material and supplies inventories are valued at average cost,
less an allowance for obsolete and surplus items.
|
|
(d) |
Property, Plant, and Equipment |
Costs for mineral properties, mineral rights, and mine
development incurred to expand capacity of operating mines or to
develop new mines are capitalized and charged to operations on
the units-of-production method over the estimated proven and
probable reserve tons. Mine development costs include costs
incurred for site preparation and development of the mines
during the development stage. Mobile mining equipment and other
fixed assets are stated at cost and depreciated on a
straight-line basis over estimated useful lives ranging from 2
to 20 years. Leasehold improvements are amortized, using
the straight-line method, over their estimated useful lives or
the term of the lease, whichever is shorter. Major repairs and
betterments that significantly extend original useful lives or
improve productivity are capitalized and depreciated over the
period benefited. Maintenance and repairs are expensed as
incurred.
|
|
(e) |
Impairment of Long-Lived Assets |
In accordance with SFAS No. 144, Accounting for the
Impairment or Disposal of Long-lived Assets, long-lived
assets, such as property, plant, equipment, and purchased
intangibles subject to amortization, are reviewed for impairment
whenever events or changes in circumstances indicate that the
carrying amount of an asset may not be recoverable.
Recoverability of assets to be held and used is measured by a
comparison of the carrying amount of an asset to estimated
undiscounted future cash flows expected to be generated by the
asset. If the carrying amount of an asset exceeds its estimated
future cash flows, an impairment charge is recognized by the
amount by which the carrying amount of the asset exceeds the
fair value of the asset. Assets to be disposed of would be
separately presented in the balance sheet and reported at the
lower of the carrying amount or fair value less costs to sell,
and would no longer be depreciated. The assets and liabilities
of a disposal group classified as held for sale would be
presented separately in the appropriate asset and liability
sections of the balance sheet.
|
|
(f) |
Goodwill and Other Intangible Assets |
Goodwill represents the excess of costs over fair value of net
assets of businesses acquired. Pursuant to
SFAS No. 142, Goodwill and Other Intangible
Assets, goodwill and intangible assets acquired in a
purchase business combination and determined to have an
indefinite useful life are not amortized, but instead tested for
impairment at least annually in accordance with the provisions
of SFAS No. 142. The Company performs its impairment
test in August of each year. SFAS No. 142 also
requires that intangible assets with estimable useful lives be
amortized over their respective estimated useful lives to their
estimated residual values, and reviewed for impairment in
accordance with SFAS No. 144. The impairment review in
August 2004 supported the carrying value of goodwill.
|
|
(g) |
Health Insurance Programs |
The Company is principally self-insured for costs of health and
medical claims. The Company utilizes commercial insurance to
cover specific claims in excess of $250.
F-37
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The Company and the Predecessor account for income taxes in
accordance with SFAS No. 109, Accounting for Income
Taxes, which requires recognition of deferred tax assets and
liabilities for the expected future tax consequences of events
that have been included in the financial statements or tax
returns. Under this method, deferred tax assets and liabilities
are determined based on the difference between the financial
statement and tax bases of assets and liabilities using enacted
tax rates in effect for the year in which those items are
expected to reverse.
|
|
(i) |
Asset Retirement Obligation |
Minimum standards for mine reclamation have been established by
various regulatory agencies and dictate the reclamation
requirements at the Companys operations. The Company
records these reclamation obligations under the provisions of
SFAS No. 143, Accounting for Asset Retirement
Obligations. SFAS No. 143 requires the fair value
of a liability for an asset retirement obligation to be
recognized in the period in which the legal obligation
associated with the retirement of the long-lived asset is
incurred. When the liability is initially recorded, the offset
is capitalized by increasing the carrying amount of the related
long-lived asset. Over time, the liability is accreted to its
present value each period, and the capitalized cost is
depreciated over the useful life of the related asset. To settle
the liability, the obligation is paid, and to the extent there
is a difference between the liability and the amount of cash
paid, a gain or loss upon settlement is recorded. The Company
annually reviews its estimated future cash flows for its asset
retirement obligation.
In connection with the business acquisitions described in
note 20, the Company recorded the fair value of the
reclamation liabilities assumed as part of the acquisitions in
accordance with SFAS No. 143.
The Predecessor charged expenditures relating to environmental
regulatory requirements and reclamation costs undertaken during
mine operations against earnings as incurred. Estimated site
restoration and post-closure reclamation costs were charged
against earnings using the units-of-production method over the
expected economic life of each mine. Accrued reclamation costs
were subject to review by our Predecessors management on a
regular basis and were revised when appropriate for changes in
future estimated costs and/or regulatory requirements.
Lease rights to coal lands are often acquired in exchange for
royalty payments. Advance mining royalties are advance payments
made to lessors under terms of mineral lease agreements that are
recoupable against future production. These advance payments are
deferred and charged to operations as the coal reserves are
mined. The Company regularly reviews recoverability of advance
mining royalties and establishes or adjusts the allowance for
advance mining royalties as necessary using the specific
identification method. In instances where advance payments are
not expected to be offset against future production royalties,
the Company establishes a provision for losses on the advance
payments that have been paid and the scheduled future minimum
payments are expensed and recognized as liabilities. Advance
royalty balances are charged off against the allowance when the
lease rights are either terminated or expire.
F-38
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The changes in the allowance for advance mining royalties were
as follows:
|
|
|
|
|
Balance as of December 31, 2003 and 2002
|
|
$ |
|
|
Provision for non-recoupable advance mining royalties
|
|
|
758 |
|
Write-offs of advance mining royalties
|
|
|
(11 |
) |
|
|
|
|
Balance as of December 31, 2004
|
|
$ |
747 |
|
|
|
|
|
The Company recognizes revenue on coal sales when title passes
to the customer in accordance with the terms of the sales
agreement. Revenue from domestic coal sales is recorded at the
time of shipment or delivery to the customer, and the customer
takes ownership and assumes risk of loss based on shipping
terms. Revenue from international coal sales is recorded at the
time coal is loaded onto the shipping vessel, when the customer
takes ownership and assumes risk of loss. In the event that new
contracts are negotiated with a customer and shipments commence
before the old contract is complete, the Company recognizes as
revenue the lower of the cumulative amount billed or an amount
based on the weighted average price of the new and old contracts
applied to the tons sold.
Freight and handling costs paid to third-party carriers and
invoiced to coal customers are recorded as freight and handling
costs and freight and handling revenues, respectively.
Other revenues generally consist of equipment and parts sales,
equipment rebuild and maintenance services, coal handling and
processing, trucking services for unrelated parties, royalties,
commissions on coal trades, and rental income. These revenues
are recognized in the period earned or when the service is
completed.
|
|
(l) |
Deferred Financing Costs |
In connection with obtaining financing, the Company incurred
deferred financing costs totaling $10,525, $5,181, and $340
during the years ended December 31, 2004 and 2003, and the
period from December 14, 2002 to December 31, 2002,
respectively. These financing costs have been deferred and are
included in other assets in the accompanying combined balance
sheets. Also see note 12. These deferred financing costs
are being amortized to interest expense over the life of the
related indebtedness or credit facility. Amortization expense
for the years ended December 31, 2004 and 2003, and the
period from December 14, 2002 to December 31, 2002
totaled $4,474, $1,276, and $59, respectively. Due to the
termination of a prior credit facility, amortization expense for
the year ended December 31, 2004 includes a $2,819
write-off of deferred financing costs.
|
|
(m) |
Virginia Coalfield Employment Enhancement Tax
Credit |
For tax years 1996 through 2007, Virginia companies with an
economic interest in coal earn tax credits based upon tons sold,
seam thickness, and employment levels. The maximum credit earned
equals $0.40 per ton for surface mined coal and $1.00 or
$2.00 per ton for deep mined coal depending on seam
thickness. Credits allowable are reduced from the maximum
amounts if employment levels are not maintained from the
previous year, and no credit is allowed for coal sold to
Virginia utilities. Currently, the cash benefit of the credit is
realized three years after being earned and either offsets taxes
imposed by Virginia at 100% or is refundable by the state at 85%
of the face value to the extent taxes are not owed. The Company
records the present value of the portion of the credit that is
refundable as a reduction of operating costs as it is earned.
The Company records the portion of the credit that is allocated
to Alpha NR Holding, Inc. as an other asset. The Company records
the portion of the credit that is allocated to ANR Fund IX
Holdings, L.P. and minority interest owners as noncash
distributions.
F-39
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
(n) |
Workers Compensation and Pneumoconiosis (Black Lung)
Benefits |
The Company is self-insured for workers compensation
claims at certain of its operations in West Virginia.
Workers compensation at all other locations in West
Virginia is insured through the West Virginia state insurance
program. Workers compensation claims at locations in all
other states where the Company operates are covered by a
third-party insurance provider.
The liabilities for workers compensation claims that are
self-insured are estimates of the ultimate losses incurred based
on the Companys experience, and include a provision for
incurred but not reported losses. Adjustments to the probable
ultimate liabilities are made annually based on an actuarial
study and adjustments to the liability are recorded based on the
results of this study.
The Company is required by federal and state statutes to provide
benefits to employees for awards related to black lung. These
claims are covered by a third-party insurance provider in all
locations where the Company operates with the exception of West
Virginia. The Company is self-insured for state black lung
related claims at certain locations in West Virginia.
The liabilities for state black lung related claims in West
Virginia that are self-insured are estimates of the ultimate
losses incurred based on the Companys experience, and
include a provision for incurred but not reported losses.
Estimates of the liabilities are made annually based on an
actuarial study and adjustments to the liability are recorded
based on the results of this study.
The Company did not assume any responsibility for workers
compensation or black lung claims incurred by any of its
subsidiaries prior to their acquisition. Also see note 20.
|
|
(o) |
Postretirement Benefits Other Than Pensions |
The Company accounts for health care and life insurance benefits
provided for current and certain retired employees and their
dependents by accruing the cost of such benefits over the
service lives of employees. Unrecognized actuarial gains and
losses are amortized over the estimated average remaining
service period for active employees and over the estimated
average remaining life for retirees.
The accompanying combined financial statements include the
accounts of the Company and its majority owned subsidiaries.
Investments in unconsolidated subsidiaries representing
ownership of at least 20% but less than 50% are accounted for
under the equity method. Under the equity method of accounting,
the Companys proportionate share of the investment
companys income is included in the Companys net
income or loss with a corresponding increase or decrease in the
carrying value of the investment.
|
|
(q) |
Equity-Based Compensation Awards |
The Company accounts for equity-based compensation awards
granted to employees in accordance with Accounting Principles
Board (APB) Opinion No. 25, Accounting for Stock
Issued to Employees, and related interpretations.
Compensation cost for equity-based awards is recognized in an
amount equal to the difference between the exercise price of the
award and the fair value of the Companys equity on the
date of grant. In accordance with APB Opinion No. 25, the
Company recognized compensation expense of $91 related to the
period from the grant date on November 10, 2004 (see
note 16(e)) to December 31, 2004
F-40
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
for equity-based awards that had an exercise price less than the
fair value of the Companys common shares on the grant date.
The following table illustrates the effect on net income as if
the Company had applied the fair value recognition provisions of
SFAS No. 123 to equity-based employee compensation
using the Black-Scholes option-pricing model for 2004:
|
|
|
|
|
|
|
For the Year Ended | |
|
|
December 31, 2004 | |
|
|
| |
Reported net income
|
|
$ |
20,015 |
|
Add: Equity-based compensation expense included in reported net
income, net of income taxes and minority interest
|
|
|
50 |
|
Deduct: Total equity-based compensation expense determined under
fair-value based method, net of income taxes and minority
interest
|
|
|
(72 |
) |
|
|
|
|
Pro forma net income
|
|
$ |
19,993 |
|
|
|
|
|
The Company had not granted equity-based awards prior to
November 2004. The fair value of equity-based awards granted in
November 2004 was estimated on the date of the grant using the
Black-Scholes option pricing model with the following
assumptions:
|
|
|
|
|
Expected life (years)
|
|
|
4.0 |
|
Expected volatility
|
|
|
38.0 |
% |
Risk-free interest rate
|
|
|
3.38 |
% |
Expected annual dividend
|
|
$ |
0.10 |
|
As described in note 16(e), the options granted in November
2004 to purchase units of ACM were automatically converted into
options to purchase 596,985 shares of Alpha Natural
Resources, Inc. common stock in connection with the Internal
Restructuring on February 11, 2005. The weighted-average
fair value of options granted in 2004 was $9.04 on an as
converted basis.
The effects on pro forma net income of expensing the estimated
fair value of equity-based awards are not necessarily
representative of the effects on reported net income for future
periods due to such factors as the vesting periods of stock
options and the potential issuance of additional awards in
future years.
|
|
(r) |
New Accounting Pronouncements |
In November 2004, the Financial Accounting Standards Board (the
FASB) issued SFAS No. 151, Inventory Costs,
which amends the guidance in Accounting Research Bulletin
(ARB) No. 43, Chapter 4, Inventory
Pricing, to clarify the accounting for abnormal amounts of
idle facility expense, freight, handling costs, and wasted
material (spoilage). SFAS No. 151 clarifies that
abnormal amounts of idle facility expense, freight, handling
costs, and wasted materials (spoilage) should be recognized
as current-period charges instead of inventory costs. The
provisions of this pronouncement will be effective for inventory
costs incurred during fiscal years ending after June 15,
2005. The Company is currently evaluating whether the adoption
of SFAS No. 151 will have any material financial
statement impact.
In December 2004, the FASB issued SFAS No. 123(R),
Share-Based Payment, which requires companies to expense
the fair value of equity awards over the required service
period. This Statement is a revision of SFAS No. 123,
Accounting for Stock-Based Compensation.
SFAS No. 123(R) supersedes APB Opinion No. 25,
Accounting for Stock Issued to Employees, which uses the
intrinsic value method to value stock-based compensation. The
effective date of SFAS No. 123(R) will be as of the
beginning of the first interim or annual reporting period that
begins after June 15, 2005. There are various methods of
adopting
F-41
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
SFAS No. 123(R), and the Company has not yet
determined what method it will use. The Company will adopt
SFAS No. 123(R) effective July 1, 2005.
In December 2004, the FASB issued SFAS No. 153,
Exchanges of Nonmonetary Assets, an amendment of APB Opinion
No. 29, Accounting for Nonmonetary Transactions. This
Statements amendments are based on the principle that
exchanges of nonmonetary assets should be measured based on the
fair value of the assets exchanged. Further,
SFAS No. 153 eliminates the narrow exception for
nonmonetary exchanges of similar productive assets and replaces
it with a broader exception for exchanges of nonmonetary assets
that do not have commercial substance. The provisions of this
pronouncement will be effective for nonmonetary asset exchanges
occurring in fiscal periods beginning after June 15, 2005.
The Company does not expect the adoption of
SFAS No. 153 will have any material financial
statement impact.
The preparation of the combined financial statements in
conformity with U.S. generally accepted accounting
principles requires management to make estimates and assumptions
that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues
and expenses during the reporting period. Significant items
subject to such estimates and assumptions include the allowance
for doubtful accounts; inventories; mineral reserves; allowance
for non-recoupable advance mining royalties; asset retirement
obligations; employee benefit liabilities; future cash flows
associated with assets; useful lives for depreciation,
depletion, and amortization; workers compensation and
black lung claims; postretirement benefits other than pensions;
income taxes; and fair value of financial instruments. Due to
the subjective nature of these estimates, actual results could
differ from those estimates.
Certain prior period amounts have been reclassified to conform
to the current year presentation.
|
|
(3) |
Notes and Other Receivables |
Notes and other receivables consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Notes receivable
|
|
$ |
5,986 |
|
|
$ |
577 |
|
Other receivables
|
|
|
4,849 |
|
|
|
4,165 |
|
|
|
|
|
|
|
|
|
Total notes and other receivables
|
|
$ |
10,835 |
|
|
$ |
4,742 |
|
|
|
|
|
|
|
|
As part of a coal purchase agreement, the Company loaned an
unrelated coal supplier $10,000 on June 10, 2004 at a
variable interest rate to be repaid in installments over a
two-year period beginning in August 2004. The loan is secured by
the assets of the company and personally guaranteed by the
companys owner. As of December 31, 2004, $5,398 of
the outstanding amount is included in current notes and other
receivables and $3,083 is included in other assets.
F-42
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Inventories consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Raw coal
|
|
$ |
3,888 |
|
|
$ |
4,710 |
|
Saleable coal
|
|
|
42,899 |
|
|
|
23,629 |
|
Materials and supplies
|
|
|
7,782 |
|
|
|
4,774 |
|
|
|
|
|
|
|
|
|
Total inventories
|
|
$ |
54,569 |
|
|
$ |
33,113 |
|
|
|
|
|
|
|
|
|
|
(5) |
Prepaid Expenses and Other Current Assets |
Prepaid expenses and other current assets consisted of the
following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Prepaid insurance
|
|
$ |
16,577 |
|
|
$ |
15,643 |
|
Advance mining royalties
|
|
|
4,831 |
|
|
|
1,928 |
|
Refundable income taxes
|
|
|
2,798 |
|
|
|
|
|
Other prepaid expenses
|
|
|
4,709 |
|
|
|
1,685 |
|
|
|
|
|
|
|
|
|
Total prepaid expenses and other current assets
|
|
$ |
28,915 |
|
|
$ |
19,256 |
|
|
|
|
|
|
|
|
|
|
(6) |
Property, Plant, and Equipment |
Property, plant, and equipment consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Land
|
|
$ |
5,380 |
|
|
$ |
4,514 |
|
Mineral rights
|
|
|
85,245 |
|
|
|
89,652 |
|
Plant and mining equipment
|
|
|
188,891 |
|
|
|
121,442 |
|
Vehicles
|
|
|
2,058 |
|
|
|
1,976 |
|
Mine development
|
|
|
11,205 |
|
|
|
2,333 |
|
Office equipment and software
|
|
|
7,264 |
|
|
|
5,865 |
|
Construction in progress
|
|
|
1,769 |
|
|
|
2,592 |
|
|
|
|
|
|
|
|
|
|
|
301,812 |
|
|
|
228,374 |
|
Less accumulated depreciation, depletion, and amortization
|
|
|
83,848 |
|
|
|
30,227 |
|
|
|
|
|
|
|
|
|
Property, plant, and equipment, net
|
|
$ |
217,964 |
|
|
$ |
198,147 |
|
|
|
|
|
|
|
|
As of December 31, 2004, the Company had commitments to
purchase approximately $43,300 of new equipment, expected to be
acquired at various dates through 2005.
Depreciation expense was $50,679, $28,438, and $104 and
depletion expense was $3,541, $2,396, and $45 for the years
ended December 31, 2004 and 2003, and the period from
December 14, 2002 to December 31, 2002, respectively.
F-43
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The changes in the carrying amount of goodwill were as follows:
|
|
|
|
|
Balance as of December 31, 2002
|
|
$ |
|
|
Acquisition of U.S. AMCI
|
|
|
17,121 |
|
|
|
|
|
Balance as of December 31, 2003
|
|
|
17,121 |
|
2004 Adjustments
|
|
|
1,520 |
|
|
|
|
|
Balance as of December 31, 2004
|
|
$ |
18,641 |
|
|
|
|
|
The carrying amount of goodwill was increased by $1,520 during
the year ended December 31, 2004 due to the final
settlement of the amount of working capital acquired in the
U.S. AMCI acquisition. See note 20.
Other intangible assets consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
Estimated | |
|
| |
|
|
Remaining Life | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Sales contracts
|
|
|
3 years |
|
|
$ |
3,248 |
|
|
$ |
3,937 |
|
Noncompete agreements
|
|
|
2 years |
|
|
|
250 |
|
|
|
200 |
|
Other
|
|
|
|
|
|
|
|
|
|
|
13 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,498 |
|
|
|
4,150 |
|
Less accumulated amortization
|
|
|
|
|
|
|
2,343 |
|
|
|
1,254 |
|
|
|
|
|
|
|
|
|
|
|
|
Total other intangibles, net
|
|
|
|
|
|
$ |
1,155 |
|
|
$ |
2,896 |
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2004, aggregate annual future
amortization expense associated with other intangible assets was
as follows:
|
|
|
|
|
|
|
Years ending December 31:
|
|
|
|
|
|
2005
|
|
$ |
581 |
|
|
2006
|
|
|
436 |
|
|
2007
|
|
|
138 |
|
|
|
|
|
|
|
Total
|
|
$ |
1,155 |
|
|
|
|
|
Total amortization expense recognized on intangible assets was
$1,792, $5,220, and $125 for the years ended December 31,
2004 and 2003, and the period from December 14, 2002 to
December 31, 2002, respectively.
F-44
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Other assets consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Advance mining royalties, net
|
|
$ |
8,841 |
|
|
$ |
9,638 |
|
Deferred loan costs, net
|
|
|
10,237 |
|
|
|
3,460 |
|
Deferred common stock offering costs
|
|
|
3,665 |
|
|
|
|
|
Notes receivable
|
|
|
3,451 |
|
|
|
|
|
Investment in terminalling facility
|
|
|
1,005 |
|
|
|
1,005 |
|
Investment in Excelven Pty Ltd.
|
|
|
4,500 |
|
|
|
|
|
Virginia tax credit receivable
|
|
|
4,806 |
|
|
|
2,434 |
|
Other
|
|
|
321 |
|
|
|
1,814 |
|
|
|
|
|
|
|
|
|
Total other assets
|
|
$ |
36,826 |
|
|
$ |
18,351 |
|
|
|
|
|
|
|
|
At December 31, 2004 and 2003, the Company has a note
payable that financed certain insurance premiums in the amount
of $15,228 and $14,425, respectively. Interest and principal are
due in monthly installments, with interest at the rate of 4.39%
and 3.55% for 2004 and 2003, respectively, with the final
payment due November 13, 2005. The insurance policies
financed include workers compensation, black lung, and
property and liability coverages.
|
|
(11) |
Accrued Expenses and Other Current Liabilities |
Accrued expenses and other current liabilities consisted of the
following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Wages and employee benefits
|
|
$ |
20,201 |
|
|
$ |
12,770 |
|
Current portion of asset retirement obligation
|
|
|
6,691 |
|
|
|
7,820 |
|
Taxes other than income taxes
|
|
|
6,136 |
|
|
|
6,243 |
|
Freight
|
|
|
12,376 |
|
|
|
1,974 |
|
Contractor escrow
|
|
|
1,615 |
|
|
|
1,499 |
|
Deferred gains on sales of property interests
|
|
|
808 |
|
|
|
355 |
|
Deferred revenues
|
|
|
1,086 |
|
|
|
|
|
Current portion of self-insured workers compensation
benefits
|
|
|
1,612 |
|
|
|
450 |
|
Workers compensation insurance premium payable
|
|
|
3,567 |
|
|
|
773 |
|
Interest payable
|
|
|
1,632 |
|
|
|
210 |
|
Additional consideration on acquisition
|
|
|
5,000 |
|
|
|
|
|
Accrued stock offering costs
|
|
|
2,010 |
|
|
|
|
|
Other
|
|
|
5,549 |
|
|
|
3,048 |
|
|
|
|
|
|
|
|
|
Total accrued expenses and other current liabilities
|
|
$ |
68,283 |
|
|
$ |
35,142 |
|
|
|
|
|
|
|
|
F-45
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Long-term debt consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
10% Senior notes due 2012
|
|
$ |
175,000 |
|
|
$ |
|
|
Revolving credit facility
|
|
|
8,000 |
|
|
|
10,000 |
|
Variable rate term loan
|
|
|
|
|
|
|
45,000 |
|
Seller financing (El Paso CGP Company)
|
|
|
|
|
|
|
8,000 |
|
8.75% term notes
|
|
|
|
|
|
|
4,664 |
|
Variable rate term notes
|
|
|
1,466 |
|
|
|
2,679 |
|
Capital lease obligation
|
|
|
1,995 |
|
|
|
|
|
Other
|
|
|
16 |
|
|
|
196 |
|
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
|
186,477 |
|
|
|
70,539 |
|
|
Less current portion
|
|
|
1,693 |
|
|
|
13,329 |
|
|
|
|
|
|
|
|
|
|
Long-term debt, net of current portion
|
|
$ |
184,784 |
|
|
$ |
57,210 |
|
|
|
|
|
|
|
|
On May 18, 2004, Alpha and its wholly-owned subsidiary,
Alpha Natural Resources Capital Corp., issued $175,000 of
10% senior notes due June 2012 in a private placement
offering under Rule 144A of the Securities Act of 1933, as
amended, resulting in net proceeds of approximately $171,500
after fees and other offering costs. The senior notes are
unsecured but are guaranteed fully and unconditionally on a
joint and several basis by all of Alphas wholly-owned
domestic restricted subsidiaries. Interest is payable
semi-annually in June and December. Additional interest on the
senior notes is payable in certain circumstances if a
registration statement with respect to an offer to exchange the
notes for a new issue of equivalent notes registered under the
Securities Act has not been declared effective on or prior to
February 14, 2005 (270 days after the notes were
issued), or if the offer to exchange the notes is not
consummated within 30 business days after February 14,
2005. The amount of this additional interest is equal to 0.25%
of the principal amount of the notes per annum during the first
90-day period after a failure to have the registration statement
declared effective or consummate the exchange offer, and it will
increase by an additional 0.25% per annum with respect to
each subsequent 90-day period until the registration statement
has been declared effective and the exchange offer has been
consummated, up to a maximum amount of additional interest of
1.0% per annum.
On May 28, 2004, Alpha entered into a new revolving credit
facility with a group of lending institutions led by Citicorp
North America, Inc., as administrative agent (Citicorp Credit
Facility). The Citicorp Credit Facility, as amended, provides
for a revolving line of credit of up to $125,000 and a funded
letter of credit facility of up to $50,000. As of
December 31, 2004, the Company had $8,000 principal amount
in borrowings outstanding under the revolving line of credit and
$2,991 in letters of credit outstanding, leaving $114,009
available for borrowing. As of December 31, 2004, the
funded letter of credit facility was fully utilized at $50,000
at an annual fee of 3.1% of the outstanding amount. Amounts
drawn under the revolver bear interest at a variable rate based
upon either the prime rate or a London Interbank Offered Rate
(LIBOR), in each case plus a spread that is dependent on our
leverage ratio. The interest rate applicable to our borrowings
under the revolver was 7.0% as of December 31, 2004. The
principal balance of the revolving credit note is due in May
2009. ANR Holdings and each of the subsidiaries of Alpha have
guaranteed Alphas obligations under the revolving credit
facility. The obligations of Alpha, ANR Holdings and
Alphas subsidiaries under the Citicorp Credit Facility are
collateralized by all of the assets of Alpha, ANR Holdings and
Alphas subsidiaries. The Citicorp Credit Facility contains
various
F-46
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
affirmative and negative covenants which, among others,
establish net worth, interest coverage and leverage ratio
requirements. The Company must pay an annual commitment fee up
to a maximum of
1/2
of 1% of the unused portion of the commitment. The Company was
in compliance with its debt covenants under the Citicorp Credit
Facility as of December 31, 2004.
Prior to May 28, 2004, the Company had a term loan and
revolving credit facility with a group of lending institutions
led by PNC Bank (PNC). As of December 31, 2003, $45,000
principal amount was outstanding under the term loan. The term
note had a variable interest rate (4.39% at December 31,
2003) and was payable in quarterly principal installments of
$2,250 plus interest, with a final balloon payment due
March 11, 2006. The PNC credit facility provided for a
revolving line of credit of up to $75,000. As of
December 31, 2003, $10,000 principal amount and letters of
credit totaling $24,014 were outstanding. Amounts drawn under
the revolver had a variable interest rate (3.92% at
December 31, 2003). The principal balance of the revolving
credit note was due March 11, 2006. ANR Holdings and each
of the subsidiaries of the Company had guaranteed Alphas
obligations under the credit facility. The Company paid an
annual commitment fee of
1/2
of 1% of the unused portion of the commitment. The PNC term loan
and credit facility were paid in full on May 28, 2004.
In conjunction with the purchase of Coastal Coal Company, LLC,
the Company issued a note payable to El Paso CGP on
January 31, 2003. The balance of the note at
December 31, 2003 was $8,000. The note had a fixed interest
rate of 14% and was due on March 11, 2009. This note was
paid in full in May 2004.
In conjunction with the purchase of the U.S. coal
production and marketing operations of AMCI (U.S. AMCI) on
March 11, 2003, the Company assumed term notes payable to
Komatsu Financial LP. The balance of the notes at
December 31, 2003, was $3,719. The notes had fixed interest
rates with a weighted average of 8.75% at December 31,
2003, and were payable in monthly installments ranging from $4
to $24, through August 1, 2006. These notes were paid in
full in May 2004.
The Company has term notes payable to The CIT Group Equipment
Financing, Inc. in the amount of $1,466 at December 31,
2004 and $2,679 at December 31, 2003. The term notes bear
interest at variable rates with a rate of 5.71% at
December 31, 2004 and a weighted average rate of 4.84% at
December 31, 2003 and are payable in monthly installments
ranging from $34 to $64, through April 2, 2006.
In conjunction with the purchase of U.S. AMCI, the Company
assumed term notes payable to the Caterpillar Financial Services
Corporation. The balance of the notes at December 31, 2003,
was $945. The notes had a fixed interest rate of 8.75% and were
payable in monthly installments ranging from $9 to $25, through
October 5, 2004. These notes were paid in full in May 2004.
The Company issued notes payable to Pittston Coal Company for
the purchase of certain assets of that company on
December 13, 2002. The balance of the notes at
December 31, 2002, was $25,743. In 2003, the notes were
paid in full.
The Company entered into a capital lease for equipment in
conjunction with the purchase of substantially all of the assets
of Moravian Run Reclamation Co., Inc. on April 1, 2004. The
lease has a term of sixty months with monthly payments ranging
from $20 to $60 with a final balloon payment of $180 in March
2009. The effective interest rate on the capital lease is
approximately 12.15%. The capitalized cost of the leased
property was $1,995 at December 31, 2004. Accumulated
amortization was $378 at December 31, 2004. Amortization
expense on capital leases is included with depreciation expense.
The Companys long-term debt is collateralized by
substantially all assets of the Company.
F-47
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Future maturities of long-term debt, including capital lease
obligations, are as follows as of December 31, 2004:
|
|
|
|
|
|
|
Year ending December 31:
|
|
|
|
|
|
2005
|
|
$ |
1,693 |
|
|
2006
|
|
|
736 |
|
|
2007
|
|
|
500 |
|
|
2008
|
|
|
316 |
|
|
2009
|
|
|
8,232 |
|
|
Thereafter
|
|
|
175,000 |
|
|
|
|
|
|
|
Total long-term debt
|
|
$ |
186,477 |
|
|
|
|
|
Following is a schedule of future minimum lease payments under
capital lease obligations together with the present value of the
net minimum lease payments as of December 31, 2004:
|
|
|
|
|
|
|
Year ending December 31:
|
|
|
|
|
|
2005
|
|
$ |
720 |
|
|
2006
|
|
|
600 |
|
|
2007
|
|
|
600 |
|
|
2008
|
|
|
360 |
|
|
2009
|
|
|
240 |
|
|
|
|
|
|
|
Total future minimum lease payments
|
|
|
2,520 |
|
Less amount representing interest
|
|
|
(525 |
) |
|
|
|
|
|
|
Present value of future minimum lease payments
|
|
|
1,995 |
|
Less current portion
|
|
|
(505 |
) |
|
|
|
|
|
|
Long-term capital lease obligation
|
|
$ |
1,490 |
|
|
|
|
|
|
|
(13) |
Asset Retirement Obligation |
At December 31, 2004 and 2003, the Company has recorded
asset retirement obligation accruals for mine reclamation and
closure costs totaling $39,579 and $40,427, respectively. The
portion of the costs expected to be incurred within a year in
the amount of $6,691 and $7,820, at December 31, 2004 and
2003, respectively, is included in accrued expenses and other
current liabilities. These regulatory
F-48
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
obligations are secured by surety bonds in the amount of $91,394
at December 31, 2004 and $84,512 at December 31, 2003.
Changes in the reclamation obligation were as follows:
|
|
|
|
|
|
Pittston Coal Company acquisition
|
|
$ |
15,050 |
|
Accretion for 2002
|
|
|
57 |
|
|
|
|
|
|
Total asset retirement obligation at December 31, 2002
|
|
|
15,107 |
|
Coastal Coal Company, LLC acquisition
|
|
|
12,861 |
|
U.S. AMCI acquisition
|
|
|
8,768 |
|
Mears Enterprises, Inc. acquisition
|
|
|
2,079 |
|
Accretion for 2003
|
|
|
2,699 |
|
Sites added in 2003
|
|
|
1,165 |
|
Expenditures in 2003
|
|
|
(2,252 |
) |
|
|
|
|
|
Total asset retirement obligation at December 31, 2003
|
|
|
40,427 |
|
Accretion for 2004
|
|
|
3,301 |
|
2004 acquisitions
|
|
|
1,189 |
|
Sites added in 2004
|
|
|
3,657 |
|
Revisions in estimated cash flows
|
|
|
(5,689 |
) |
Expenditures in 2004
|
|
|
(3,306 |
) |
|
|
|
|
|
Total asset retirement obligation at December 31, 2004
|
|
$ |
39,579 |
|
|
|
|
|
|
|
(14) |
Deferred Gains on Sales of Property Interests |
In February 2003, the Company sold an overriding royalty
interest in certain mining properties for $11,850. The gain on
this transaction in the amount of $850 was deferred and is being
amortized over the associated remaining term of the mineral
lease. This property interest was acquired from El Paso CGP
Company in the acquisition of the Coastal Coal properties.
In April 2003, the Company sold mineral properties for $53,625
in a sale/leaseback transaction. These properties had originally
been acquired from Pittston Coal Company. The estimated gain on
this transaction in the amount of $7,057 was deferred and is
being amortized over the ten-year term of the lease. Also see
note 20.
The Company recognized $959 and $618 of the above deferred gains
for the years ended December 31, 2004 and 2003,
respectively. In addition, for the year ended December 31,
2004, the deferred gain was increased by $3,514 for revisions in
estimated cash flows underlying the asset retirement obligation
relating to the mineral properties which had been sold,
increased by $1,480 for revisions in the estimated contract
reclamation liability assumed in conjunction with the
acquisition of the Virginia coal operations of Pittston Coal
Company, and decreased by $5,000 relating to the accrual of
additional consideration for the acquisition of the Virginia
coal operations of Pittston Coal Company.
|
|
(15) |
Fair Value of Financial Instruments |
The estimated fair values of financial instruments under
SFAS No. 107, Disclosures About Fair Value of
Financial Instruments, are determined based on relevant
market information. These estimates involve uncertainty and
cannot be determined with precision. The following methods and
assumptions are used to estimate the fair value of each class of
financial instrument.
F-49
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Cash and Cash Equivalents, Trade Accounts Receivables,
Note Payable, Bank Overdraft, Trade Accounts Payable, and
Other Current Liabilities: The carrying amounts approximate
fair value due to the short maturity of these instruments.
Notes Receivable: The fair value approximates the
carrying value as the rates associated with the receivables are
comparable to current market rates.
Long-term Debt: The fair value of the 10% Senior
notes is based on the trading price of the notes. The fair value
of debt with variable interest rates is equal to the principal
amount of the notes since the interest rates are reset
periodically. The fair value of other long-term debt is based on
the current market rate of interest offered to the Company for
debt of similar maturities. The estimated fair values of
long-term debt were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
10% Senior notes
|
|
$ |
209,970 |
|
|
$ |
|
|
Variable rate term loan
|
|
|
|
|
|
|
45,000 |
|
Revolving credit facility
|
|
|
8,000 |
|
|
|
10,000 |
|
8.75% term notes
|
|
|
|
|
|
|
4,725 |
|
Variable rate term notes
|
|
|
1,466 |
|
|
|
2,679 |
|
Seller financing
|
|
|
|
|
|
|
10,100 |
|
Capital lease obligation
|
|
|
2,196 |
|
|
|
|
|
Other
|
|
|
16 |
|
|
|
196 |
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
$ |
221,648 |
|
|
$ |
72,700 |
|
|
|
|
|
|
|
|
|
|
(16) |
Employee Benefit Plans |
|
|
|
(a) Postretirement Benefits Other Than Pensions |
Three of the Companys subsidiaries assumed collective
bargaining agreements as part of two acquisitions that require
these subsidiaries to provide postretirement medical benefits to
certain employees who retire after the acquisition closing
dates. In each case, however, The Brinks Company and AMCI,
as sellers, have retained the obligation to provide
postretirement medical benefits to employees who retired prior
to the acquisition closing dates (December 13, 2002 and
March 11, 2003, respectively) and to employees who were not
retained by these subsidiaries. In addition, The Brinks
Company retained the obligation to provide postretirement
medical benefits to a significant number of the employees who
have worked for the Company after the acquisition closing,
namely, those employees who met the eligibility criteria by
December 31, 2003, even if the employees will not retire
until sometime in the future. These plans are unfunded and the
measurement date is December 31 of each year.
Effective July 1, 2004, the Company adopted a plan offering
postretirement medical benefits to active union-free employees
that will provide a credit of $20 per month per year of
service for pre-65 year old and $9 per month per year
of service for post-65 year old retirees toward the
purchase of medical benefits (as defined) from the Company. The
adoption of this new plan resulted in prior service cost of
$27,122 which will be amortized over the remaining service of
the union-free employees.
F-50
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The components of the change in accumulated benefit obligations
of the plans for postretirement benefits other than pensions
were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
|
|
December 14, | |
|
|
Year Ended December 31, | |
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Change in benefit obligation:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated benefit obligation-beginning of period:
|
|
$ |
11,532 |
|
|
$ |
5,951 |
|
|
$ |
|
|
|
|
Service cost
|
|
|
2,266 |
|
|
|
656 |
|
|
|
19 |
|
|
|
Interest cost
|
|
|
1,375 |
|
|
|
580 |
|
|
|
17 |
|
|
|
Actuarial (gain) or loss
|
|
|
1,526 |
|
|
|
(15 |
) |
|
|
|
|
|
|
Benefits paid
|
|
|
(38 |
) |
|
|
|
|
|
|
|
|
|
|
Prior service cost
|
|
|
27,122 |
|
|
|
|
|
|
|
|
|
|
|
Postretirement benefits assumed in acquisitions
|
|
|
|
|
|
|
3,475 |
|
|
|
5,915 |
|
|
|
Change due to discount rate assumption
|
|
|
|
|
|
|
885 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated benefit obligation-end of period
|
|
$ |
43,783 |
|
|
$ |
11,532 |
|
|
$ |
5,951 |
|
|
|
|
|
|
|
|
|
|
|
Funded status
|
|
$ |
(43,783 |
) |
|
$ |
(11,532 |
) |
|
$ |
(5,951 |
) |
Unrecognized prior service cost
|
|
|
25,725 |
|
|
|
|
|
|
|
|
|
Unrecognized net actuarial loss
|
|
|
2,421 |
|
|
|
870 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accrued postretirement medical benefits
|
|
$ |
(15,637 |
) |
|
$ |
(10,662 |
) |
|
$ |
(5,951 |
) |
|
|
|
|
|
|
|
|
|
|
The following table details the components of the net periodic
benefit cost for postretirement benefits other than pensions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
Year Ended | |
|
December 14, | |
|
|
December 31, | |
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Service cost
|
|
$ |
2,266 |
|
|
$ |
656 |
|
|
$ |
19 |
|
Interest cost
|
|
|
1,375 |
|
|
|
580 |
|
|
|
17 |
|
Amortization of net (gain) or loss
|
|
|
(24 |
) |
|
|
|
|
|
|
|
|
Amortization of prior service cost
|
|
|
1,396 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic benefit cost
|
|
$ |
5,013 |
|
|
$ |
1,236 |
|
|
$ |
36 |
|
|
|
|
|
|
|
|
|
|
|
The discount rates used in determining the benefit obligations
as of December 31, 2004, 2003 and 2002 were 5.75%, 6.25%,
and 6.75%, respectively. The discount rates used in determining
net periodic postretirement benefit cost were 6.25%, 6.75% and
6.75% for the years ended December 31, 2004 and 2003, and
period from December 14, 2002 to December 31, 2002,
respectively.
The weighted average annual rate of increase in the per capita
cost of covered benefits (i.e., health care trend rate) for
medical benefits assumed is 12% for 2004, decreasing to 5% in
2010 and thereafter.
F-51
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Assumed health care trend rates have a significant effect on the
amounts reported for the health care plans. A
one-percentage-point change in assumed health care trend rates
would have the following effects as of and for the year ended
December 31, 2004:
|
|
|
|
|
|
|
|
|
|
|
One | |
|
One | |
|
|
Percentage | |
|
Percentage | |
|
|
Point | |
|
Point | |
|
|
Increase | |
|
Decrease | |
|
|
| |
|
| |
Effect on accumulated postretirement benefit obligation
|
|
$ |
2,626 |
|
|
$ |
(1,964 |
) |
Effect on total service and interest cost components
|
|
|
301 |
|
|
|
(235 |
) |
Employer contributions for benefits paid for the year ended
December 31, 2004 were $38. Employee contributions are not
expected to be made and the plan is unfunded.
Estimated future benefit payments reflecting expected future
service for the fiscal years ending after December 31, 2004
are as follows:
|
|
|
|
|
|
|
Year ending December 31:
|
|
|
|
|
|
2005
|
|
$ |
39 |
|
|
2006
|
|
|
67 |
|
|
2007
|
|
|
126 |
|
|
2008
|
|
|
388 |
|
|
2009
|
|
|
690 |
|
|
2010-2014
|
|
|
9,709 |
|
|
|
|
|
|
|
Total
|
|
$ |
11,019 |
|
|
|
|
|
On December 8, 2003, the President of the United States
signed into law the Medicare Prescription Drug, Improvement and
Modernization Act of 2003 (the Act). The Act
introduces a prescription drug benefit under Medicare
(Medicare Part D) as well as a federal subsidy
to sponsors of retiree heath care benefit plans that provide a
benefit that is at least actuarially equivalent to Medicare
Part D.
At December 31, 2003, in accordance with FASB Staff
Position No. FAS 106-1, Accounting and Disclosure
Requirements related to the Medicare Prescription Drug,
Improvement and Modernization Act of 2003 (FSP
106-1), the Company elected to defer recognition of the
effects of the Act in any measures of the benefit obligation or
cost.
In May 2004, the FASB issued further guidance with the release
of FASB Staff Position No. FAS 106-2, Accounting
and Disclosure Requirements related to the Medicare Prescription
Drug, Improvement and Modernization Act of 2003 (FSP
106-2). The Company has reflected the estimated impact of
the Act as a $629 reduction in the present value of the
accumulated postretirement benefit obligation as of
January 1, 2004 and a $113 reduction in the net periodic
service cost for the year ended December 31, 2004.
The Company sponsors a 401(k) Savings-Investment Plan to assist
its eligible employees in providing for retirement. The Company
contributes 3% of compensation, as defined, for every employee
who is eligible to participate in the plan. Participants also
receive a 50% matching contribution from the Company of up to 4%
of their total compensation, as defined. The effective date of
the plan was February 1, 2003. Total Company contributions
for the years ended December 31, 2004 and 2003, were
$5,086, and $3,505, respectively.
F-52
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
|
(c) Self-Insured Medical Plan |
The Company is self-insured for health insurance coverage
provided for all of its employees. During the years ended
December 31, 2004 and 2003, and the period from
December 14, 2002 to December 31, 2002, total claims
expense of $18,094, $12,313, and $355, respectively, was
incurred, which represents claims processed and an estimate for
claims incurred but not reported.
|
|
|
(d) Multi-Employer Pension Plan |
Three of the Companys subsidiaries assumed collective
bargaining agreements as part of two acquisitions that require
them to participate in the United Mine Workers of America
(UMWA) 1950 and 1974 pension plans. These plans are
multi-employer pension plans whereby the expense is based upon
defined contribution rates. There was no expense under these
plans for the years ended December 31, 2004 and 2003, or
for the period from December 14, 2002 to December 31,
2002 as no contributions were required.
Two of the three subsidiaries referenced above are required to
make contributions to the 1993 UMWA Benefit Plan of fifty cents
per signatory hour worked. The contributions that the Company
made to this plan for the years ended December 31, 2004 and
2003 were $31 and $29, respectively.
|
|
|
(e) Equity-Based Compensation Awards |
In November 2004, ACM adopted the Alpha Coal Management LLC 2004
Long-Term Incentive Plan (the Alpha Coal Management
Long-Term Incentive Plan) to provide equity-based
incentive compensation to those key employees and others who
make significant contributions to the strategic and long-term
performance objectives and growth of the Company. On
November 10, 2004, ACM granted options to
purchase 800,000 units of ACM to 22 members of the
Companys management team under the Alpha Coal Management
Long-Term Incentive Plan. These options vest over a period of
five years (with accelerated vesting upon a change of control)
and have a term of ten years. In connection with this grant of
options, ACM entered into a letter agreement with ANR Holdings
pursuant to which ANR Holdings agreed to issue to ACM additional
membership interests representing sharing ratios in the
aggregate amount equal to 1% of the outstanding membership
interests upon exercise of awards granted by ACM under the Alpha
Coal Management Long-Term Incentive Plan. In connection with the
Internal Restructuring on February 11, 2005, this plan was
amended and restated, the outstanding options to purchase units
of ACM were automatically converted into options to purchase
shares of Alpha Natural Resources, Inc. common stock and Alpha
Natural Resources, Inc. assumed the obligations of ACM pursuant
to this plan. After the Internal Restructuring, there are
outstanding under the plan options to purchase an aggregate of
596,985 shares of common stock (the maximum number of
shares currently available for awards under the plan) at an
exercise price of $12.73 per share. No additional options
or awards will be granted under the plan.
In connection with the Internal Restructuring, Alpha Natural
Resources, Inc. adopted, and its stockholders approved, the
Alpha Natural Resources, Inc. Long-Term Incentive Plan (the
Long-Term Incentive Plan). The principal purpose of
the Long-Term Incentive Plan is to attract, motivate, reward and
retain selected employees, consultants and directors through the
granting of stock-based compensation awards. The Long-Term
Incentive Plan provides for a variety of awards, including
non-qualified stock options, incentive stock options (within the
meaning of Section 422 of the Code), stock appreciation
rights, restricted stock awards, dividend equivalents,
performance-based awards and other stock-based awards.
The total number of shares of Alpha Natural Resources, Inc.
common stock initially available for issuance or delivery under
the Long-Term Incentive Plan is 3,338,841 shares, and the
maximum number
F-53
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
of shares that may be subject to awards made to any one plan
participant in any fiscal year will be 2,000,000 shares.
Subsequent to December 31, 2004, Alpha Natural Resources,
Inc. granted certain of its executive officers, directors and
key employees options to purchase an aggregate of
692,905 shares of Alpha Natural Resources, Inc. common
stock at the initial public offering price at the time of the
initial public offering. The number of shares of Alpha Natural
Resources, Inc. common stock issued or reserved pursuant to the
Long-Term Incentive Plan is subject, at the discretion of the
board of directors (or the committee if so empowered), to
adjustment as a result of stock splits, stock dividends and
similar changes in Alpha Natural Resources, Inc. common stock.
The Company did not assume the Predecessors obligations
under the following employee benefit plans:
The Combined Virginia Entitys union-free employees who met
certain eligibility requirements participated in The
Brinks Companys noncontributory defined benefit
pension plans (the Brinks Plans). Benefits under the
Brinks Plans were based on salary (including commissions,
bonuses, overtime, and premium pay) and years of service.
For the purpose of preparing the Predecessors combined
financial statements, the Combined Virginia Entitys
projected benefit obligation at December 13, 2002 relating
to its participation in the Brinks Plans was actuarially
estimated based on data, such as years of service, salary, and
age, for employees of companies included in the Combined
Virginia Entity.
The fair value of plan assets and unrecognized experience loss
and prior service cost were allocated to the Combined Virginia
Entity as of December 13, 2002 based on the Combined
Virginia Entitys pro rata share of The Brinks
Companys projected benefit obligation. The Brinks
Companys policy was to fund at least the minimum
actuarially determined amounts necessary in accordance with
applicable regulations.
The net pension credit for the period from January 1, 2002
to December 13, 2002 for all plans was as follows:
|
|
|
|
|
|
|
|
Period from | |
|
|
January 1, | |
|
|
2002 to | |
|
|
December 13, | |
|
|
2002 | |
|
|
| |
Service cost
|
|
$ |
2,504 |
|
Interest cost on Projected Benefit Obligation (PBO)
|
|
|
8,547 |
|
Return on assets expected
|
|
|
(12,617 |
) |
Other amortization, net
|
|
|
638 |
|
|
|
|
|
|
Net pension credit
|
|
$ |
(928 |
) |
|
|
|
|
F-54
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The assumptions used in determining the net pension credit and
funded status for the Combined Virginia Entitys pension
plans were as follows:
|
|
|
|
|
|
|
Period from | |
|
|
January 1, | |
|
|
2002 to | |
|
|
December 13, | |
|
|
2002 | |
|
|
| |
Discount rate-expense
|
|
|
7.25% |
|
Discount rate-funded status
|
|
|
6.75% |
|
Expected long-term rate of return on assets (expense)
|
|
|
10.00% |
|
Expected long-term rate of return on assets (funded status)
|
|
|
8.75% |
|
Average rate of increase in salaries (expense and funded
status)(1)
|
|
|
4.00% |
|
|
|
(1) |
Salary scale assumptions varied by age and approximated
4% per annum. |
Reconciliations of the PBO, plan assets, funded status, and
prepaid pension asset at December 13, 2002 for the Combined
Virginia Entitys pension plans was as follows:
|
|
|
|
|
|
|
Period from | |
|
|
January 1, | |
|
|
2002 to | |
|
|
December 13, | |
|
|
2002 | |
|
|
| |
PBO at beginning of period
|
|
$ |
121,760 |
|
Service cost
|
|
|
2,504 |
|
Interest cost
|
|
|
8,547 |
|
Benefits paid
|
|
|
(7,735 |
) |
Actuarial loss
|
|
|
2,679 |
|
|
|
|
|
PBO at end of period
|
|
$ |
127,755 |
|
|
|
|
|
Fair value of plan assets at beginning of period
|
|
$ |
111,438 |
|
Return on assets actual
|
|
|
(11,780 |
) |
Employer contributions
|
|
|
3,294 |
|
Benefits paid
|
|
|
(7,735 |
) |
|
|
|
|
Fair value of plan assets at end of period
|
|
$ |
95,217 |
|
|
|
|
|
Funded status
|
|
$ |
(32,538 |
) |
Unrecognized experience loss
|
|
|
59,329 |
|
|
|
|
|
Net prepaid pension assets
|
|
|
26,791 |
|
Noncurrent pension liability
|
|
|
1,319 |
|
|
|
|
|
Prepaid pension asset
|
|
$ |
28,110 |
|
|
|
|
|
The Combined Virginia Entity participated in the United Mine
Workers of America (UMWA) 1950 and 1974 pension plans at
defined contribution rates. There was no expense under these
plans in 2002 as no contribution was required. A multi-employer
pension plan withdrawal liability related to these plans of
$28,424 was accrued as of December 13, 2002 by the Virginia
Combined Entity associated with The Brinks Companys
planned exit from the coal business. The estimate was based on
the most recent actuarial estimate of liability for a withdrawal
occurring in the plan year ending June 30, 2002. The
withdrawal liability and any subsequent changes in the liability
are the responsibility of The Brinks Company.
F-55
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The Brinks Company sponsored a 401(k) Savings-Investment
Plan to assist its eligible U.S. employees in providing for
retirement. Employee contributions were matched at rates of
between 50% to 100% up to 5% of compensation (subject to certain
limitations). Contribution expense for the Combined Virginia
Entity under the plan aggregated $493 for the period from
January 1, 2002 to December 13, 2002.
|
|
|
(c) Postretirement Benefits Other Than Pensions |
The Brinks Company provided certain postretirement health
care and life insurance benefits for eligible active and retired
employees in the U.S., including those employed by the Combined
Virginia Entity (The Brinks Company sponsored plans). The
Brinks Company also provided benefits to certain eligible
employees of the Combined Virginia Entity as required by the
Health Benefit Act, discussed below.
The Brinks Company Sponsored Plans. For the purpose
of preparing the combined financial statements of the Combined
Virginia Entity, the unrecognized experience loss was allocated
to the Combined Virginia Entity based on a pro rata share of The
Brinks Companys Accumulated Postretirement Benefit
Obligation (APBO) as of December 13, 2002. For the
period from January 1, 2002 to December 13, 2002, the
components of net periodic postretirement expense related to The
Brinks Company sponsored plans for postretirement benefits
were as follows:
|
|
|
|
|
|
|
Period from | |
|
|
January 1, | |
|
|
2002 to | |
|
|
December 13, | |
|
|
2002 | |
|
|
| |
Service cost
|
|
$ |
540 |
|
Interest cost on APBO
|
|
|
14,888 |
|
Amortization of loss
|
|
|
4,413 |
|
|
|
|
|
Net periodic postretirement benefit expense
|
|
$ |
19,841 |
|
|
|
|
|
Reconciliations of the APBO, funded status, and accrued
postretirement benefit cost for the Combined Virginia
Entitys share of The Brinks Company sponsored plans
at December 13, 2002 are as follows:
|
|
|
|
|
|
|
Period from | |
|
|
January 1, | |
|
|
2002 to | |
|
|
December 13, | |
|
|
2002 | |
|
|
| |
APBO at beginning of period
|
|
$ |
211,974 |
|
Service cost
|
|
|
540 |
|
Interest cost
|
|
|
14,888 |
|
Benefits paid
|
|
|
(13,132 |
) |
Actuarial loss
|
|
|
13,103 |
|
|
|
|
|
APBO and funded status at end of period
|
|
|
227,373 |
|
Unrecognized experience loss
|
|
|
(95,542 |
) |
|
|
|
|
Accrued postretirement benefit cost at end of period
|
|
$ |
131,831 |
|
|
|
|
|
F-56
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The APBO was determined using the unit credit method and an
assumed discount rate of 6.75% in 2002. For The Brinks
Company sponsored plans, the assumed health care cost trend rate
used in 2002 was 10% for 2003, declining 1% per year to 5%
in 2008 and thereafter. The assumed Medicare cost trend rate
used in 2002 was 5%.
A one percentage point increase (decrease) each year in the
assumed health care cost trend rate used for 2002 would increase
(decrease) the aggregate service and interest components of
expense for 2002, and increase (decrease) the APBO of
Company-sponsored plans at December 13, 2002 as follows:
|
|
|
|
|
|
|
|
|
|
|
Effect of 1% Change | |
|
|
in Health Care | |
|
|
Trend Rates | |
|
|
| |
|
|
Increase | |
|
Decrease | |
|
|
| |
|
| |
Effect on total service and interest cost components
|
|
$ |
1,909 |
|
|
$ |
(1,582 |
) |
Effect on APBO
|
|
|
27,652 |
|
|
|
(22,916 |
) |
Health Benefit Act. In October 1992, the Coal Industry
Retiree Health Benefit Act (the Health Benefit Act) was enacted
as part of the Energy Policy Act of 1992. The Health Benefit Act
established rules for the payment of future health care benefits
for thousands of retired union mine workers and their
dependents. The Health Benefit Act established a trust fund to
which signatory operators and related
persons, including The Brinks Company and certain of
its subsidiaries, including some of the subsidiaries included in
the Combined Virginia Entity, are jointly and severally liable
to pay annual premiums for assigned beneficiaries, together with
a pro rata share for certain beneficiaries who never worked for
such employers (unassigned beneficiaries) in amounts determined
on the basis set forth in the Health Benefit Act. In October
1993 and at various times in subsequent years, The Brinks
Company received notices from the Social Security Administration
(the SSA) with regard to the assigned beneficiaries for which
The Brinks Company was responsible under the Health
Benefit Act. In addition, the Health Benefit Act requires The
Brinks Company to fund, pro rata according to the total
number of assigned beneficiaries, a portion of the health
benefits for unassigned beneficiaries. At this time, the funding
for such health benefits is being provided from another source;
however, the statutory authorization to obtain such funds is
currently expected to cease by 2005. In the determination of The
Brinks Companys ultimate obligation under the Health
Benefit Act, such funding has been taken into consideration.
The Combined Virginia Entity accounted for their obligations
under the Health Benefit Act as participants in a multi-employer
benefit plan, as provided by Emerging Issues Task Force
(EITF) No. 92-13, Accounting for Estimated Payments
in Connection with the Coal Industry Retiree Health Benefit Act
of 1992, and thus, recognized the annual cost of these
obligations on a pay-as-you-go basis. For the period from
January 1, 2002 to December 13, 2002, the Combined
Virginia Entitys pro rata allocated portion of the annual
premiums were $1,302. The Company has no liability under this
act.
Black Lung. The Combined Virginia Entity was self-insured
with respect to substantially all black lung
(pneumoconiosis) benefits. Provision was made for estimated
benefits based on annual reports prepared by independent
actuaries. Unamortized losses were amortized over the average
remaining life expectancy of participants (approximately
10 years). Assumptions used in the calculation of the
actuarial present value of black lung benefits were based on
actual retirement experience of the Combined Virginia
Entitys employees, black lung claims incidence, actual
dependent information, industry turnover rates, actual medical
and legal cost experience, and projected inflation rates. The
amount of expense incurred by the Combined Virginia Entity for
black lung benefits was $3,428 for the period from
January 1, 2002 to December 13, 2002.
F-57
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
(17) |
Workers Compensation Benefits |
The Companys operations generally are fully insured for
workers compensation and black lung claims. Insurance
premium expense for the years ended December 31, 2004 and
2003 was $16,192 and $15,984, respectively. A portion of the
West Virginia operations of the Company are self-insured for
workers compensation and state black lung claims. The
liability for these claims is an estimate of the ultimate losses
to be incurred on such claims based on the Companys
experience and published industry data. Adjustments to the
probable ultimate liability are made annually based on an
actuarial valuation and are included in operations as they are
determined. The obligations incurred prior to January 31,
2003 are currently secured by surety bonds of El Paso
Corporation, an unrelated entity. Also see note 23.
The liability for self-insured workers compensation benefits at
December 31, 2004 and 2003 was $6,290 and $2,110,
respectively, including a current portion of $1,612 and $450,
respectively. Workers compensation expense for the years
ended December 31, 2004 and 2003 was $7,697 and $4,464,
respectively, including fees paid to the State of West Virginia
to be self-insured. The Company is required to post bonds in the
amount of $2,288 with the state of West Virginia to secure
estimated self-insured liabilities for the period from
February 1, 2003 through June 30, 2004. The state of
West Virginia allows the self-insured companies to post these
bonds in installments to be fully secured by June 30, 2006.
The Company posted a bond of $727 as the first installment for
the year ended December 31, 2004.
|
|
(18) |
Related Party Transactions |
As of December 31, 2002, the Company had notes payable in
the amount of $23,953 payable to a related party. These notes
along with other notes in the amount of $20,047 were converted
to contributed capital of the Company in 2003. The Company
incurred interest expense on the related party notes of $2,625
and $144 during the year ended December 31, 2003 and the
period from December 14, 2002 to December 31, 2002,
respectively.
In conjunction with the purchase of U.S. AMCI from the AMCI
Parties, the Company paid $35,000 for the working capital of
U.S. AMCI, as defined in the contribution agreement,
subject to an audit. As of December 31, 2003, the net
working capital acquired was estimated to be $31,569 and the
difference of $3,431 was recorded as a receivable. In September
2004, ANR Holdings, First Reserve and the AMCI Parties
agreed that the net working capital actually acquired was
$34,070, and the AMCI Parties paid the difference of $930 to the
Company. The parties further agreed that the AMCI Parties would
be entitled to any refund of, and obligated to make any payment
of, all federal black lung excise taxes of the companies
contributed by the AMCI Parties to ANR Holdings, but only
insofar as the taxes related to pre-closing or straddle periods
ending on or prior to the closing date of the U.S. AMCI
acquisition. As a result, $981 of the previously recorded
receivable from AMCI was reclassified to offset a federal black
lung excise tax accrued liability included in the net working
capital acquired. The remaining $1,520 was recorded as an
increase to goodwill.
The Company records rent on its Latrobe, Pennsylvania operating
facility from a related party. Total rent expense was $144 and
$114 as of and for the years ended December 31, 2004 and
2003, respectively. The amount of accrued rent payable to the
related party at December 31, 2004 and 2003 was $258 and
$114, respectively.
In conjunction with the acquisition of U.S. AMCI, ANR
Holdings entered into an agreement with entities affiliated with
AMCI that requires the AMCI parties to pay reclamation and other
obligations of one of the former U.S. AMCI entities
acquired by the Company (Solomons Mining Company). In April
2004, the Company entered into an arrangement with the former
owners of U.S. AMCI (the AMCI Parties) to
purchase 350 tons of coal from a third-party at a price of
$54.50 per ton at various
F-58
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
times from April 2004 through November 2005. An amount of $34.50
will be paid to the producer of that coal, $12.00 per ton
is payable to the AMCI Parties and $8.00 per ton is
retained by the Company to fund the remaining reclamation
obligation of Solomons Mining Company. As of December 31,
2004, the Company has retained an aggregate of $1,778 under this
arrangement. After the Company has retained $2,300, the
$8.00 per ton will thereafter be paid to the U.S. AMCI
parties.
In connection with our acquisition of Coastal Coal Company, we
acquired an overriding royalty interest in certain properties
located in Virginia and West Virginia owned by El Paso CPG
Company for $11,000 in cash. Effective February 1, 2003,
the Company sold the overriding royalty interest to affiliates
of Natural Resource Partners, L.P. (NRP) for $11,850 in
cash. Effective April 1, 2003, the Company also sold
substantially all of its fee-owned Virginia mineral properties
to NRP for $53,625 in cash in a sale/leaseback transaction.
Based on the aggregate of $20,219 and $16,028 that the Company
paid to NRP in lease, royalty and property tax reimbursement
payments for the years ended December 31, 2004 and 2003,
respectively, NRP is our largest landlord. As of
December 31, 2004 and 2003, the Company had $1,430 and
$1,290, respectively, in accounts payable to NRP. In an
unrelated transaction in December 2003, a member of the ANR
Holdings and Alpha Natural Resources, Inc. board of directors
was appointed as a member of the board of directors of
GP Natural Resource Partners, LLC, the general partner of
NRP, and First Reserve became a substantial equity owner of NRP.
The Company believes the production and minimum royalty rates
contained in leases with NRP are consistent with current market
royalty rates.
One of Alpha Natural Resources, LLCs Executive Vice
Presidents is a 50% owner of Robindale Energy Services, Inc.
(and its subsidiary) (Robindale). Robindale is
engaged in the business of waste coal sales and related
businesses in Pennsylvania. From time to time, Robindale has
sold and purchased coal and related products to the operations
of our AMFIRE regional business unit in Pennsylvania. For the
years ended December 31, 2004 and 2003, our subsidiaries
Alpha Coal Sales and AMFIRE Mining Company, LLC had purchases of
$799 and $172, respectively, from Robindale for trucking
services and waste coal. For the year ended December 31,
2004, the Company had sales of $206 to Robindale. The
outstanding payable to and receivable from Robindale were $42
and $6, respectively, as of December 31, 2004. The Company
has agreed that our Executive Vice Presidents continued
relationship with Robindale will not cause a breach of his
employment agreement with us, and he has agreed that he will not
participate in any decisions to enter into any transactions that
might be proposed between Robindale and Alpha.
In April 2004, we entered into a coal sales arrangement with
AMCI Metall & Kohle AG to sell 750 metric
tons through March 2005. Two of the ANR Holdings and Alpha
Natural Resources, Inc. board members hold ownership in AMCI
Metall & Kohle AG. For the year ended
December 31, 2004, total sales of $46,315 have been
recorded under this contract. The receivable balance due from
AMCI Metall & Kohle AG was $7,121 at
December 31, 2004. The Company also had total sales of
$14,872 for the year ended December 31, 2004 to AMCI
Australia Pty Ltd., an entity owned by two of the Companys
board members. The Company purchased coal in the amount of
$1,658 under various short-term purchase orders and recorded
sales of $248 during the year ended December 31, 2004 to
XCoal Energy and Resources, an entity in which two members of
Alphas board of directors each own more than a 10% equity
interest. The Company had an outstanding payable amount of $4 as
of December 31, 2004 due to XCoal Energy and Resources. In
addition, American Metals and Coal International, Inc., an
entity owned by two of the Companys board members,
facilitated a $5,202 coal sales transaction with an
international buyer for no compensation or commission. For the
year ended December 31, 2003 the Company recorded sales in
the amount of $5,859 and purchases in the amount of $8,983 with
affiliates of the AMCI Parties. The outstanding payable amount
due to AMCI affiliates was $998 at December 31, 2003.
F-59
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
One of the Companys subsidiaries purchased $4,799 of coal
in the ordinary course of our business from subsidiaries of
Foundation Coal Holdings, Inc. (Foundation). The
balance payable as of December 31, 2004 was $822. Three of
the Companys directors also serve as directors of
Foundation. First Reserve Fund IX, L.P. and an entity
affiliated with AMCI beneficially own an aggregate of
approximately 24% of the outstanding shares of Foundations
common stock.
The Combined Virginia Entity had receivables and payables and
was a party to certain transactions with affiliated companies in
the normal course of business.
Pittston Coal Management Company (PCMC) provided executive,
legal, engineering, geological, accounting, and other
administrative services to affiliated companies owned directly
or indirectly by Pittston Coal Company, including companies
included in the Combined Virginia Entity.
PCMC allocated its costs to the various entities based primarily
on production, head count, and asset base. Intercompany balances
among companies included in the Combined Virginia Entity have
been eliminated, and net amounts due from other affiliated
companies are classified in the balance sheet as a component of
shareholders equity.
Pittston Coal Sales Corporation (PCSC) provided services to
affiliated companies owned by Pittston Coal Company, including
companies included in the Combined Virginia Entity. PCSC
negotiated and entered into coal sales contracts with customers
using its sales staff. A portion of the cost of PCSCs
sales department was allocated to the affiliated companies based
on relative coal sales volume. Coal was shipped from affiliated
coal production companies, including companies included in the
Combined Virginia Entity, to customers and PCSC invoiced the
customers and recorded a payable to the affiliated company for
the amount of the customer invoice. PCSC collected the cash on
behalf of the affiliate. Intercompany balances between PCSC and
companies included in the Combined Virginia Entity have been
eliminated and receivables and payables to other affiliated
companies were classified as a component of shareholders
equity.
Cash generated or used by our Predecessor was ultimately
received or provided by The Brinks Company. During the
period from January 1, 2002 to December 13, 2002,
Pittston Coal Company contributed $329,964, respectively, of
intercompany amounts owned by its subsidiaries included in the
Combined Virginia Entity to shareholders equity.
Our Predecessor was included in the consolidated
U.S. federal income tax return filed by The Brinks
Company. The Brinks Companys consolidated provision
and actual cash payments for U.S. federal income taxes were
allocated between the Predecessor and other affiliates of The
Brinks Company in accordance with The Brinks
Companys tax allocation policy. In general, the
consolidated current tax provision of The Brinks
Companys was allocated among the affiliates based
principally upon the financial income, taxable income, credits,
and other amounts directly related to the respective affiliate.
The Brinks Company gave credit to its subsidiaries for the
tax effect of U.S. federal income tax losses and other
attributes to the extent the attributes were utilized on a
consolidated basis. As a result, the allocated affiliate amounts
of taxes payable or refundable are not necessarily comparable to
those that would have resulted if the affiliate had filed
separate tax returns. Net deferred income tax assets of the
Predecessor are reflected as deferred income tax receivable from
parent and are classified as a component of shareholders
equity.
F-60
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The Company leases coal mining and other equipment under
long-term operating leases with varying terms. In addition, the
Company leases mineral interests and surface rights from land
owners under various terms and royalty rates.
As of December 31, 2004, aggregate future minimum lease
payments under operating leases and minimum royalties under coal
leases were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equipment | |
|
Coal | |
|
|
|
|
Facility | |
|
and Other | |
|
Royalties | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
Year ending December 31:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005
|
|
$ |
481 |
|
|
$ |
3,826 |
|
|
$ |
9,212 |
|
|
$ |
13,519 |
|
|
2006
|
|
|
279 |
|
|
|
3,767 |
|
|
|
8,616 |
|
|
|
12,662 |
|
|
2007
|
|
|
211 |
|
|
|
2,206 |
|
|
|
8,752 |
|
|
|
11,169 |
|
|
2008
|
|
|
168 |
|
|
|
524 |
|
|
|
7,770 |
|
|
|
8,462 |
|
|
2009
|
|
|
77 |
|
|
|
|
|
|
|
7,739 |
|
|
|
7,816 |
|
|
Thereafter
|
|
|
261 |
|
|
|
|
|
|
|
30,031 |
|
|
|
30,292 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
1,477 |
|
|
$ |
10,323 |
|
|
$ |
72,120 |
|
|
$ |
83,920 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The above table includes amounts due under noncancelable leases
with initial or remaining lease terms in excess of one year.
Net rent expense amounted to $6,290 for the year ended
December 31, 2004, $6,113 for the year ended
December 31, 2003, $170 for the period from
December 14, 2002 to December 31, 2002, and $8,262 for
the period from January 1, 2002 to December 13, 2002.
Coal royalties expense amounted to $43,858 for the year ended
December 31, 2004, $29,027 for the year ended
December 31, 2003, $46 for the period from
December 14, 2002 to December 31, 2002, and $981 for
the period from January 1, 2002 to December 13, 2002.
As of December 31, 2004, the Company had commitments to
purchase 6.2 million, 1.6 million, and
0.8 million tons of coal at a cost of $342,422, $79,143,
and $31,320 in 2005, 2006, and 2007, respectively. As part of a
coal supply tonnage buyout agreement, at December 31, 2004,
the Company had commitments to pay the customer $680 each year
from 2005 to 2009, and $567 in 2010.
|
|
(20) |
Mergers and Acquisitions |
On December 13, 2002, the Company acquired the majority of
the Virginia coal assets of Pittston Coal Company (the Combined
Virginia Entity), for a net purchase price of $62,945. The
results of the Combined Virginia Entitys operations have
been included in the combined financial statements since that
date. The purchase also included Maxxim Rebuild, a mining
equipment and repair business.
The $62,945 purchase price for the Combined Virginia Entity
consisted of a $37,202 cash payment at closing, and notes
payable of $25,743 issued to the seller, $18,500 of which was in
the form of a minimum royalty agreement. Additional payments of
up to $5,000 are payable under the royalty agreement if certain
F-61
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
levels of coal sales prices are achieved. As of
December 31, 2004, $5,000 had been accrued for this
additional consideration.
In conjunction with the acquisition, the Company contracted with
the Predecessor to perform reclamation work for sites retained
by the Predecessor. As of December 31, 2004, the Company
had $1,364 in liabilities related to the remaining contract
reclamation work, including a current portion of $711.
The following table summarizes the estimated fair values, as
determined by an independent third-party valuation, of the
assets acquired and liabilities assumed at the date of
acquisition (December 13, 2002):
|
|
|
|
|
|
Current assets
|
|
$ |
17,732 |
|
Property, plant, and equipment
|
|
|
69,087 |
|
Intangible assets
|
|
|
4,091 |
|
|
|
|
|
|
Total assets acquired
|
|
|
90,910 |
|
|
|
|
|
Asset retirement obligation
|
|
|
(15,050 |
) |
Postretirement medical benefits
|
|
|
(5,915 |
) |
Other liabilities
|
|
|
(7,000 |
) |
|
|
|
|
|
Total liabilities assumed
|
|
|
(27,965 |
) |
|
|
|
|
|
Net assets acquired
|
|
$ |
62,945 |
|
|
|
|
|
On January 31, 2003, the Company acquired 100% of the
membership interest of Coastal Coal Company, LLC and certain
other assets. The results of Coastal Coals operations have
been included in the combined financial statements since that
date. Coastal Coal Company, LLC is a producer of thermal and
industrial coals in the Appalachian region.
The aggregate net purchase price for the Coastal Coal membership
interest and related assets was $67,772. Consideration included
cash of $44,172 and notes payable issued to the seller of
$23,600.
F-62
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The following table summarizes the estimated fair values, as
determined by an independent third-party valuation, of the
assets acquired and liabilities assumed at the date of
acquisition (January 31, 2003):
|
|
|
|
|
|
Current assets
|
|
$ |
31,614 |
|
Property, plant, and equipment
|
|
|
40,342 |
|
Intangibles
|
|
|
3,937 |
|
Other noncurrent assets
|
|
|
18,269 |
|
|
|
|
|
|
Total assets acquired
|
|
|
94,162 |
|
|
|
|
|
Current liabilities
|
|
|
(11,700 |
) |
Asset retirement obligation
|
|
|
(12,861 |
) |
Other noncurrent liabilities
|
|
|
(1,431 |
) |
Notes payable
|
|
|
(398 |
) |
|
|
|
|
|
Total liabilities assumed
|
|
|
(26,390 |
) |
|
|
|
|
|
Net assets acquired
|
|
$ |
67,772 |
|
|
|
|
|
|
|
|
American Metals and Coal International, Inc. |
On March 11, 2003, the Company acquired the majority of the
North American operations of American Metals and Coal
International, Inc. (U.S. AMCI). The results of
U.S. AMCIs operations have been included in the
combined financial statements since that date. U.S. AMCI is
a producer of Appalachian coal and a broker of steam and
metallurgical coals in the United States and abroad.
The aggregate purchase price for the U.S. AMCI net assets
was $121,299. Consideration included cash of $52,339, and common
and preferred membership interests in ANR Holdings issued,
valued at $68,960. The value attributed to the membership
interest was based on the cash contributions made by the other
owners of ANR Holdings.
The goodwill represents the portion of the purchase price
allocated to the U.S. AMCI sales force. The goodwill is not
deductible for federal income tax purposes.
F-63
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The following table summarizes the estimated fair values, as
determined by an independent third-party valuation, of the
assets acquired and liabilities assumed at the date of
acquisition (March 11, 2003):
|
|
|
|
|
|
Current assets
|
|
$ |
47,005 |
|
Property, plant, and equipment
|
|
|
94,732 |
|
Goodwill
|
|
|
17,121 |
|
Other noncurrent assets
|
|
|
976 |
|
|
|
|
|
|
Total assets acquired
|
|
|
159,834 |
|
|
|
|
|
Current liabilities
|
|
|
(17,307 |
) |
Asset retirement obligation
|
|
|
(8,768 |
) |
Postretirement medical benefits
|
|
|
(3,475 |
) |
Other noncurrent liabilities
|
|
|
(1,051 |
) |
Notes payable
|
|
|
(7,934 |
) |
|
|
|
|
|
Total liabilities assumed
|
|
|
(38,535 |
) |
|
|
|
|
|
Net assets acquired
|
|
$ |
121,299 |
|
|
|
|
|
On November 17, 2003, the Company acquired the assets of
Mears Enterprises, Inc (Mears Enterprises) and affiliated
companies. The results of Mears Enterprises and affiliates
operations have been included in the combined financial
statements since that date. Mears Enterprises and affiliates
operate six mining complexes and a preparation plant, all
located in Pennsylvania.
The aggregate purchase price for the net assets of Mears
Enterprises and affiliates was $37,977 in cash.
The following table summarizes the estimated fair values, as
determined by an independent third-party valuation, of the
assets acquired and liabilities assumed at the date of
acquisition (November 17, 2003):
|
|
|
|
|
|
Current assets
|
|
$ |
280 |
|
Property, plant, and equipment
|
|
|
39,476 |
|
Intangibles
|
|
|
200 |
|
Other noncurrent assets
|
|
|
100 |
|
|
|
|
|
|
Total assets acquired
|
|
|
40,056 |
|
Asset retirement obligation
|
|
|
(2,079 |
) |
|
|
|
|
|
Net assets acquired
|
|
$ |
37,977 |
|
|
|
|
|
|
|
|
Moravian Run Reclamation Co. |
On April 1, 2004, the Company acquired substantially all of
the assets of Moravian Run Reclamation Co., Inc. (Moravian Run)
for $5 in cash. The Company has agreed to pay Moravian Run
monthly overriding royalty payments for the next four years in
an aggregate amount of $1,000 and monthly payments for the next
five years in respect of leased equipment in an aggregate amount
of $3,100 structured as a capital lease with a present value of
$2,360. The Company also assumed $1,086 of
F-64
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
reclamation obligations. The Moravian Run assets included, as of
March 31, 2004, four active surface mines and two
additional surface mines under development, operating in close
proximity to and serving many of the same customers as our
AMFIRE business unit located in Pennsylvania.
|
|
|
Cooney Bros. Coal Company |
On May 10, 2004, the Company acquired a coal preparation
plant and railroad loading facility located in Portage,
Pennsylvania and related equipment and coal inventory from
Cooney Bros. Coal Company for $2,500 in cash and an adjacent
coal refuse disposal site from a Cooney family trust for $300 in
cash. The Company also assumed approximately $102 of reclamation
obligations in connection with this acquisition.
The Moravian Run Reclamation Co. and Cooney Bros. Coal Company
acquisitions are not significant to the Companys financial
position, results of operations, or cash flows and, therefore,
are not included in the pro forma information presented below.
The following unaudited pro forma financial information for the
year ended December 31, 2003 reflects the consolidated
results of operations of the Company as if the acquisitions of
Coastal Coal Company, LLC, U.S. AMCI, and Mears Enterprises
and affiliates had taken place on January 1, 2003. The pro
forma information includes primarily adjustments for
depreciation and depletion on acquired property, plant, and
equipment, and interest expense. The pro forma financial
information is not necessarily indicative of the results of
operations had the transactions been completed on the assumed
date.
|
|
|
|
|
Revenues
|
|
$ |
902,766 |
|
Net income
|
|
|
5,769 |
|
|
|
(21) |
Concentrations and Major Customers |
The Company markets its coal principally to electric utilities
in the United States and international and domestic steel
producers. As of December 31, 2004 and 2003, trade accounts
receivable from electric utilities totaled approximately $30,900
and $32,700, respectively. Credit is extended based on an
evaluation of the customers financial condition and
collateral is generally not required. Credit losses are provided
for in the combined financial statements and historically have
been minimal. The Company is committed under long-term contracts
to supply coal that meets certain quality requirements at
specified prices. The prices for some multi-year contracts are
adjusted based on economic indices or the contract may include
year-to-year specified
price changes. Quantities sold under some contracts may vary
from year to year within certain limits at the option of the
customer. Sales to the Companys largest customer in 2004
and 2003 accounted for less than 10% of total sales for the
years ended December 31, 2004 and 2003.
The Company extracts, processes and markets steam and
metallurgical coal from surface and deep mines for sale to
electric utilities, steel and coke producers, and industrial
customers. The Company operates only in the United States with
mines in the Central Appalachian and Northern Appalachian
regions and in Colorado. The Company has one reportable segment:
Coal Operations, consisting of 43 underground mines and
21 surface mines located in Central Appalachia and Northern
Appalachia as of December 31, 2004, and one underground
mine located in Colorado. Coal Operations also includes the
Companys purchased coal sales function, which markets the
Companys Appalachian coal to domestic and international
customers. The All Other category includes the Companys
equipment sales and repairs operations, as well as other
ancillary business activities, including terminal services,
trucking services, coal and environmental analysis services, and
leasing of mineral rights. The Corporate and Eliminations
F-65
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
category includes general corporate overhead and the elimination
of intercompany transactions. The revenue elimination amount
represents inter-segment revenues. The Company evaluates the
performance of its segment based on EBITDA, as adjusted, which
the Company defines as net income (loss) plus interest expense,
income tax expense (benefit), depreciation, depletion and
amortization, less interest income, and adjusted for minority
interest.
EBITDA, as adjusted, from continuing operations is defined as
income (loss) from continuing operations plus interest expense,
income tax expense (benefit), depreciation, depletion and
amortization, less interest income, and adjusted for minority
interest.
Operating segment results for continuing operations for the year
ended December 31, 2004 and segment assets as of
December 31, 2004 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Combined | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
1,234,640 |
|
|
$ |
28,571 |
|
|
$ |
(10,509 |
) |
|
$ |
1,252,702 |
|
Depreciation, depletion, and amortization
|
|
|
51,732 |
|
|
|
1,435 |
|
|
|
2,094 |
|
|
|
55,261 |
|
EBITDA, as adjusted
|
|
|
166,159 |
|
|
|
2,808 |
|
|
|
(43,877 |
) |
|
|
125,090 |
|
Capital expenditures
|
|
|
68,940 |
|
|
|
332 |
|
|
|
1,167 |
|
|
|
70,439 |
|
Total assets
|
|
|
396,935 |
|
|
|
105,727 |
|
|
|
(25,541 |
) |
|
|
477,121 |
|
Operating segment results for continuing operations for the year
ended December 31, 2003 and segment assets as of
December 31, 2003 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Combined | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
771,791 |
|
|
$ |
18,277 |
|
|
$ |
(8,219 |
) |
|
$ |
781,849 |
|
Depreciation, depletion, and amortization
|
|
|
32,421 |
|
|
|
1,867 |
|
|
|
1,097 |
|
|
|
35,385 |
|
EBITDA, as adjusted
|
|
|
69,098 |
|
|
|
719 |
|
|
|
(21,873 |
) |
|
|
47,944 |
|
Capital expenditures
|
|
|
21,656 |
|
|
|
516 |
|
|
|
5,210 |
|
|
|
27,382 |
|
Total assets
|
|
|
342,019 |
|
|
|
70,797 |
|
|
|
(33,480 |
) |
|
|
379,336 |
|
Operating segment results for continuing operations for the
period from December 14, 2002 to December 31, 2002 and
segment assets as of December 31, 2002 were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate | |
|
|
|
|
Coal | |
|
|
|
and | |
|
|
|
|
Operations | |
|
All Other | |
|
Eliminations | |
|
Combined | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
7,269 |
|
|
$ |
101 |
|
|
$ |
|
|
|
$ |
7,370 |
|
Depreciation, depletion, and amortization
|
|
|
273 |
|
|
|
1 |
|
|
|
|
|
|
|
274 |
|
EBITDA, as adjusted
|
|
|
(10 |
) |
|
|
(17 |
) |
|
|
(471 |
) |
|
|
(498 |
) |
Capital expenditures
|
|
|
564 |
|
|
|
|
|
|
|
396 |
|
|
|
960 |
|
Total assets
|
|
|
80,706 |
|
|
|
27,340 |
|
|
|
396 |
|
|
|
108,442 |
|
F-66
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Reconciliation of total segment EBITDA, as adjusted, to income
(loss) from continuing operations follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
|
|
December 14, | |
|
|
Year Ended December 31, | |
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Total segment EBITDA, as adjusted from continuing operations
|
|
$ |
125,090 |
|
|
$ |
47,944 |
|
|
$ |
(498 |
) |
Interest expense
|
|
|
(20,041 |
) |
|
|
(7,848 |
) |
|
|
(203 |
) |
Interest income
|
|
|
531 |
|
|
|
103 |
|
|
|
6 |
|
Income tax (expense) benefit
|
|
|
(5,150 |
) |
|
|
(898 |
) |
|
|
334 |
|
Depreciation, depletion and amortization
|
|
|
(55,261 |
) |
|
|
(35,385 |
) |
|
|
(274 |
) |
Minority interest
|
|
|
(22,781 |
) |
|
|
(1,164 |
) |
|
|
0 |
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
$ |
22,388 |
|
|
$ |
2,752 |
|
|
$ |
(635 |
) |
|
|
|
|
|
|
|
|
|
|
The Company markets produced, processed and purchased coal to
customers in the United States and in international markets.
Export revenues totaled $602,629 or approximately 47% of total
revenues, including sales to Japan of $138,032 or approximately
11% of total revenues, for the year ended December 31, 2004.
Export revenues were $220,818 or approximately 28% of total
revenues, including sales to Canada of $88,630 or approximately
11% of total revenues, for the year ended December 31,
2003. Export sales in 2004 primarily were to customers in Japan,
Canada, Brazil and various European countries. Export sales in
2003 primarily were to customers in Canada, Brazil, and various
European countries.
|
|
(a) |
Guarantees and Financial Instruments with Off-balance
Sheet Risk |
In the normal course of business, the Company is a party to
certain guarantees and financial instruments with off-balance
sheet risk, such as bank letters of credit and performance or
surety bonds. No liabilities related to these arrangements are
reflected in the Companys combined balance sheets.
Management does not expect any material losses to result from
these guarantees or off-balance sheet financial instruments. The
amount of bank letters of credit outstanding as of
December 31, 2004 is $52,991. The amount of surety bonds
currently outstanding related to the Companys reclamation
obligations is presented in note 13 to the combined
financial statements. The Company has provided guarantees for
equipment financing obtained by certain of its contract mining
operators totaling approximately $2,700. The estimated fair
value of these guarantees is not significant.
Alpha from time to time guarantees the performance of a
subsidiary on short-term sales and purchase contracts. The
subsidiaries of the Company also guarantee performance on the
Companys outstanding reclamation bonds, as well as the
Companys obligations under the Citicorp credit facility
and 10% senior notes.
The Company is involved in various legal proceedings from time
to time in the normal course of business. In managements
opinion, the Company is not currently involved in any legal
proceeding which individually or in the aggregate could have a
material effect on the financial condition, results of
operations and/or cash flows of the Company.
F-67
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
In connection with the Companys acquisition of Coastal
Coal Company, the seller, El Paso CGP Company, has
agreed to retain and indemnify the Company for all workers
compensation and black lung claims incurred prior to the
acquisition date of January 31, 2003. The majority of this
liability relates to claims in the state of West Virginia. If
El Paso CGP Company fails to honor its agreement with
the Company, then the Company would be liable for the payment of
those claims, which were estimated in April 2004 by the West
Virginia Workers Compensation Commission to be
approximately $5,369 on an undiscounted basis using claims data
through June 30, 2003. El Paso has posted a bond with
the state of West Virginia for the required discounted amount of
$3,722 for claims incurred prior to the acquisition.
|
|
(24) |
Asset Impairment Charge |
One of the Companys subsidiaries wholly owns National King
Coal, LLC (a mining company) and Gallup Transportation (a
trucking company) (collectively NKC). Since its
acquisition by the Company through August 2004, NKC has incurred
cumulative losses of $2,800. While NKC has not experienced sales
revenue growth comparable to our other operations of the
Company, it has been affected by many of the same cost
increases. As a result, we were required to assess the recovery
of the carrying value of the NKC assets. Based on that analysis,
it was determined that the assets of NKC were impaired. An
impairment charge of $5,100 was recorded in September 2004 to
reduce the carrying value of the assets of NKC to their
estimated fair value. A discounted cash flow model was used to
determine fair value.
|
|
(25) |
Supplemental Cash Flow Disclosures |
Cash paid for interest (net of amounts capitalized) for the
years ended December 31, 2004 and 2003 was $14,293 and
$6,879, respectively. Income taxes paid by the Company for the
year ended December 31, 2004 were $4,047.
Non-cash investing and financing activities are excluded from
the combined statements of cash flows.
Significant non-cash activity for the year ended
December 31, 2004 includes:
|
|
|
|
|
Increase in other assets of $2,372 for the Virginia Coalfield
Employment Enhancement Tax Credit receivable. This represents
the portion of the tax credit allocated to Alpha NR Holding, Inc. |
|
|
|
Increase in deferred common stock offering costs and accrued
expenses of $2,010 for accrued stock offering costs. |
|
|
|
Increase in asset retirement obligation and fixed assets of
$3,657 for new sites added in 2004. Net decrease in asset
retirement obligation and fixed assets of $2,937, and increase
in deferred gains on sales of property interests and decrease in
asset retirement obligation of $3,514 as a result of revisions
in estimated cash flows underlying the asset retirement
obligation. |
|
|
|
The short-term financing of prepaid insurance premiums in the
amount of $15,228. |
|
|
|
Settlement of the net working capital acquired in conjunction
with the acquisition of U.S. AMCI recorded as an increase
in goodwill of $1,520, a decrease in due from affiliate of
$2,501 and a decrease in accrued expenses of $981. |
|
|
|
Increase in deferred gains on sales of property interests and
decrease in other liabilities of $1,480 for revisions in
estimated contract reclamation liability assumed in conjunction
with the acquisition of the Virginia coal operations of Pittston
Coal Company. |
F-68
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
Decrease in deferred gains on sales of property interests of
$5,000 as a result of additional consideration payable for the
acquisition of the Virginia coal operations of Pittston Coal
Company. |
|
|
|
Construction in progress and other capital expenditures of
$1,597 recorded in accounts payable. |
Significant non-cash activity for the year ended
December 31, 2003 includes:
|
|
|
|
|
Increase in other assets of $2,434 for the Virginia Coalfield
Employment Enhancement Tax Credit receivable. This represents
the portion of the tax credit allocated to Alpha NR Holding, Inc. |
|
|
|
Increase in asset retirement obligation and fixed assets of
$1,165 for new sites added in 2003. |
|
|
|
The short-term financing of prepaid insurance premiums in the
amount of $14,425. |
|
|
|
The conversion of $44,000 of related party notes payable to
contributed capital. |
|
|
|
Seller financing of acquired entities of $23,600. |
|
|
|
Issuance of membership interests in ANR Holdings, LLC of $68,960
for the acquisition of U.S. AMCI. |
|
|
|
Construction in progress of $1,929 recorded in accounts payable. |
Significant non-cash activity for the period from
December 14, 2002 to December 31, 2002 includes:
|
|
|
|
|
Seller financing of acquired entities of $25,743. |
During the period from January 1, 2002 to December 13,
2002, the Pittston Coal Company contributed $329,964 of
intercompany payables from the Combined Virginia Entity to
shareholders equity.
On March 11, 2003, concurrent with the acquisition of
U.S. AMCI, ANR Holdings issued additional membership
interests in the aggregate amount of 45.3% to the former owners
of U.S. AMCI, Madison Capital Funding, LLC and ACM, which
is owned by certain members of management, in exchange for the
net assets of U.S. AMCI and cash. All members of ANR
Holdings, other than ACM, hold both common and preferred sharing
ratios representing membership interests. Pursuant to the
provisions of the ANR Holdings limited liability company
agreement, the income of ANR Holdings is allocated among its
members as follows:
|
|
|
|
|
First, to the holders of preferred sharing ratios on a pro rata
basis to the extent of any losses that had been allocated to
them in prior periods, |
|
|
|
Second, to the holders of preferred sharing ratios on a pro rata
basis up to the cumulative unallocated preferred yield (based on
an annual preferred yield of 12%), and |
|
|
|
Third, to the holders of common sharing ratios on a pro rata
basis. |
For purposes of allocating income in the year in which a new
member is admitted, ANR Holdings applies a proration method,
which allocates income based on the weighted-average ownership
of its membership interests for the year.
Prior to the Internal Restructuring on February 11, 2005,
the principal executive officers of Alpha and other key
employees held the entire membership interest of ACM, which in
turn owned a common membership interest in ANR Holdings. The
interest of ACM in ANR Holdings entitled ACM to receive
approximately 0.32% of the distributions made to the holders of
common membership interests in ANR
F-69
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
Holdings (which we refer to as the management members
purchased interest). In addition, ACM was entitled
to receive, subject to certain conditions, an additional
distribution of up to 5% of any profits (which we refer to as
the management members profits interest) upon
the occurrence of a liquidity event, as defined in the governing
documents of ANR Holdings. Generally, a liquidity event would
occur when ANR Holdings was sold or when it made a public sale
of equity. The provisions of ACMs limited liability
company agreement also contained put and call rights for the
benefit of the executive and Alpha, respectively, with respect
to the purchased interests and profits interests if the
employment relationship of the executive was terminated. In
general, depending on when the employment relationship was
terminated, the put and call prices were equal to (1) the
sum of the greater of (a) the members original
investment minus returns on that investment or (b) the fair
market value, as defined, of the members purchased
interest on the date the put was exercised, plus (2) a
percentage of the fair market value, as defined, of the profits
interest on the date the put was exercised, with the percentage
increasing from 50% to 100% as the length of the employment
period increased from two to four years from the date ACM was
formed. For purposes of the put and call, the agreement required
Alpha to use the same method of valuation that First Reserve
Corporation uses for purposes of reporting to its limited
partners, reduced by a 25% minority discount.
|
|
|
Dominion Terminal Associates |
As part of the Companys acquisition of the Combined
Virginia Entity, the Company acquired a 32.5% interest in
Dominion Terminal Associates (DTA). DTA is a partnership with
three other companies that operates a leased coal port terminal
in Newport News, Virginia (the Terminal). The Company accounts
for this investment under the equity method for investments. See
note 2(p). The Company did not ascribe any value to this
partnership interest when it was acquired.
The Company has the right to use 32.5% of the throughput and
ground storage capacity of the Terminal and pay for this right
based upon an allocation of costs as determined by DTA. The
Brinks Company guaranteed bonds of the partnership in the
face amount of $43,160 from the financing related to the
construction of the Terminal. The Brinks Company also paid
its proportionate share of interest on these bonds. The Company
did not assume any obligations associated with these bonds.
For the years ended December 31, 2004 and 2003, and the
period from December 14, 2002 to December 31, 2002,
the Company made advances to DTA equal to its share of allocated
costs of $3,266, $3,348, and $253, respectively, offset by
outside revenues of $1,763, $1,321 and $57, respectively. The
Company records its share of losses in DTA equal to the amount
of advances. The Company does not guarantee the obligations of
DTA and is not otherwise committed to provide further financial
support. Accordingly, the Company does not reduce its investment
below zero.
A net loss of $6,082 for the period from January 1, 2002 to
December 13, 2002 was recorded by the Predecessor relating
to this investment.
In September 2004, Alpha, together with its affiliate American
Metals and Coal International, Inc. (AMCI), entered
into a subscription deed with Excelven Pty Ltd, pursuant to
which each party agreed to acquire a 24.5% interest in Excelven
for a purchase price of $6.5 million in cash. Excelven,
through its subsidiaries, owns the rights to the Las Carmelitas
mining venture in Venezuela and the related Palmarejo export
port facility on Lake Maracaibo in Venezuela. Alpha made
payments totaling $4,500 for the year ended December 31,
2004. The investment is accounted for under the equity method,
and is included in other assets at December 31, 2004.
F-70
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
As outlined in the organizational structure in note 1, the
minority interest owners and ANR Fund IX Holdings, L.P. own
interests in ANR Holdings, a limited liability company and
pass-through entity for income tax purposes. As a pass-through
entity, ANR Holdings provides information returns reflecting the
allocated income (loss) to the minority interest owners and ANR
Fund IX Holdings, L.P. based upon their respective
ownership percentage and certain special allocations as provided
by the limited liability company agreement and the Internal
Revenue Code. The income tax consequences of the income (loss)
allocated to these owners is not reflected in the combined
financial statements.
The combined financial statements include only the current and
deferred income tax associated with Alpha NR Holding, Inc., a
taxable entity. The primary source of the income tax impact is
derived from the allocated income (loss) from ANR Holdings,
Alpha Natural Resources, LLC and its operating subsidiaries, all
of which are pass-through entities for tax purposes.
The federal and state income tax provisions from continuing
operations in 2004 and 2003 were offset by federal and state
income tax benefits included in the loss from discontinued
operations. The total income tax benefit for 2002 related to
continuing operations.
Comprehensive provision (benefit) for income taxes allocable to:
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Continuing operations
|
|
$ |
5,150 |
|
|
$ |
898 |
|
Discontinued operations
|
|
|
(1,190 |
) |
|
|
(230 |
) |
|
|
|
|
|
|
|
|
|
$ |
3,960 |
|
|
$ |
668 |
|
|
|
|
|
|
|
|
Significant components of income tax expense (benefit) from
continuing operations were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
Year Ended | |
|
December 14, | |
|
|
December 31, | |
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Current tax expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$ |
1,625 |
|
|
$ |
|
|
|
$ |
|
|
|
State
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,625 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred tax expense (benefit):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
2,918 |
|
|
|
894 |
|
|
|
(284 |
) |
|
State
|
|
|
607 |
|
|
|
4 |
|
|
|
(50 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
3,525 |
|
|
|
898 |
|
|
|
(334 |
) |
|
|
|
|
|
|
|
|
|
|
Total income tax expense (benefit):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
4,543 |
|
|
|
894 |
|
|
|
(284 |
) |
|
State
|
|
|
607 |
|
|
|
4 |
|
|
|
(50 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
$ |
5,150 |
|
|
$ |
898 |
|
|
$ |
(334 |
) |
|
|
|
|
|
|
|
|
|
|
F-71
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
A reconciliation of the statutory federal income tax expense
(benefit) at 35% to income (loss) from continuing operations
before income taxes and minority interest, and the actual income
tax expense (benefit) is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
Year Ended | |
|
December 14, | |
|
|
December 31, | |
|
2002 to | |
|
|
| |
|
December 31, | |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Federal statutory income tax expense (benefit)
|
|
$ |
17,612 |
|
|
$ |
1,685 |
|
|
$ |
(339 |
) |
Increases (reductions) in taxes due to:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percentage depletion allowance
|
|
|
(3,376 |
) |
|
|
(1,087 |
) |
|
|
(33 |
) |
|
Extraterritorial income exclusion
|
|
|
(1,225 |
) |
|
|
|
|
|
|
|
|
|
State taxes, net of federal tax impact
|
|
|
395 |
|
|
|
3 |
|
|
|
|
|
|
Change in valuation allowance
|
|
|
559 |
|
|
|
815 |
|
|
|
|
|
|
Taxes not provided for minority interest
|
|
|
(8,189 |
) |
|
|
(625 |
) |
|
|
|
|
|
Taxes not provided for pass-through entity
|
|
|
(779 |
) |
|
|
91 |
|
|
|
37 |
|
|
Other, net
|
|
|
153 |
|
|
|
16 |
|
|
|
1 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Actual income tax expense (benefit)
|
|
$ |
5,150 |
|
|
$ |
898 |
|
|
$ |
(334 |
) |
|
|
|
|
|
|
|
|
|
|
Deferred income taxes result from temporary differences between
the reporting of amounts for financial statement purposes and
income tax purposes. The net deferred tax assets and liabilities
included in the combined financial statements include the
following amounts:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Deferred tax assets:
|
|
|
|
|
|
|
|
|
|
Net operating loss carryforwards
|
|
$ |
5,598 |
|
|
$ |
1,956 |
|
|
Charitable contribution carryforwards
|
|
|
207 |
|
|
|
118 |
|
|
Alternative minimum tax credit carryforward
|
|
|
1,249 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross deferred tax assets
|
|
|
7,054 |
|
|
|
2,074 |
|
|
Less valuation allowance
|
|
|
(1,374 |
) |
|
|
(815 |
) |
|
|
|
|
|
|
|
|
|
Total net deferred tax assets
|
|
|
5,680 |
|
|
|
1,259 |
|
|
|
|
|
|
|
|
Deferred tax liabilities:
|
|
|
|
|
|
|
|
|
|
Investment in limited liability company subsidiary
|
|
|
(6,869 |
) |
|
|
(653 |
) |
|
Virginia tax credit
|
|
|
(1,855 |
) |
|
|
(940 |
) |
|
|
|
|
|
|
|
|
|
Total deferred tax liabilities
|
|
|
(8,724 |
) |
|
|
(1,593 |
) |
|
|
|
|
|
|
|
|
|
|
Net deferred tax liability
|
|
$ |
(3,044 |
) |
|
$ |
(334 |
) |
|
|
|
|
|
|
|
F-72
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
The breakdown of the net deferred tax liability is recorded in
the accompanying combined balance sheets as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Current asset
|
|
$ |
4,674 |
|
|
$ |
489 |
|
Current liability
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net current asset
|
|
|
4,674 |
|
|
|
489 |
|
|
|
|
|
|
|
|
Noncurrent asset
|
|
|
1,006 |
|
|
|
770 |
|
Noncurrent liability
|
|
|
(8,724 |
) |
|
|
(1,593 |
) |
|
|
|
|
|
|
|
|
Net noncurrent liability
|
|
|
(7,718 |
) |
|
|
(823 |
) |
|
|
|
|
|
|
|
|
|
Total net deferred tax liability
|
|
$ |
(3,044 |
) |
|
$ |
(334 |
) |
|
|
|
|
|
|
|
As of December 31, 2004, the Company has a net operating
loss carryforward (NOL) for federal income tax purposes of
$14,875, which is available to offset future federal taxable
income, if any, through 2024. Also, the Company has a
contribution carryforward of $591 which can be carried forward
for a maximum of five years from the year generated. In
addition, the Company has an alternative minimum tax
(AMT) credit carryforward of $1,249 which can be carried
forward indefinitely to offset future regular tax in excess of
AMT. Due to the likelihood that the AMT will exceed the regular
tax in the future, the Company has provided a valuation
allowance for the portion of deferred tax assets not expected to
be realized. The remaining net deferred tax liability, net of
the valuation allowance, reflects the AMT expected to be paid on
the net taxable temporary differences.
The Combined Virginia Entity was subject to U.S. federal
and state income taxes. The income tax benefit consisted of the
U.S. federal income taxes:
|
|
|
|
|
|
|
Period from | |
|
|
January 1, | |
|
|
2002 to | |
|
|
December 31, | |
|
|
2002 | |
|
|
| |
Current
|
|
$ |
9,175 |
|
Deferred
|
|
|
8,023 |
|
|
|
|
|
Total
|
|
$ |
17,198 |
|
|
|
|
|
The following table accounts for the difference between the
actual income tax benefit and the amounts obtained by applying
the statutory U.S. federal income tax rate of 35% to the
loss before income taxes.
|
|
|
|
|
|
|
|
|
December 13, | |
|
|
2002 | |
|
|
| |
Tax (benefit) expense computed at statutory rate
|
|
$ |
(14,532 |
) |
Increase (reductions) in taxes due to:
|
|
|
|
|
|
Percentage depletion
|
|
|
(1,302 |
) |
|
Adjustment resulting from favorable appeal relating to prior
years
|
|
|
(1,678 |
) |
|
Miscellaneous
|
|
|
314 |
|
|
|
|
|
|
|
Actual income tax benefit
|
|
$ |
(17,198 |
) |
|
|
|
|
F-73
ANR FUND IX HOLDINGS, L.P. AND ALPHA NR HOLDING, INC. AND
SUBSIDIARIES
NOTES TO COMBINED FINANCIAL
STATEMENTS (Continued)
|
|
(29) |
Federal Black Lung Excise Tax |
On February 10, 1999, the U.S. District Court of the
Eastern District of Virginia entered a final judgment in favor
of certain of The Brinks Companys subsidiaries,
including certain of the companies included in the Combined
Virginia Entity, ruling that the Federal Black Lung Excise Tax
(FBLET) is unconstitutional as applied to export coal
sales. The Brinks Company sought refunds of the FBLET it
paid on export coal sales for all open statutory periods and
received refunds of $2,758 (including interest), of which $2,049
related to the Combined Virginia Entity, during the period from
January 1, 2002 to December 13, 2002.
|
|
(30) |
Discontinued Operations and Subsequent Event |
On April 14, 2005, the Company sold the assets of its
Colorado mining subsidiary, National King Coal LLC, and related
trucking subsidiary, Gallup Transportation and Transloading
Company, LLC (collectively, NKC), to an unrelated
third party for cash in the amount of $4,400, plus an amount in
cash equal to the fair market value of NKCs coal
inventory, and the assumption by the buyer of certain
liabilities of NKC. The Company recorded a gain on the sale of
NKC of $704 in the second quarter of 2005. The results of
operations of NKC for the current and prior periods have been
reported in discontinued operations. National King Coal LLC was
previously reported in the Coal Operations segment and Gallup
Transportation and Transloading Company, LLC was previously
reported in the All Other segment (note 22).
The following statement of operations data reflects the activity
for the discontinued operation for the years ended
December 31, 2004 and 2003:
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Total revenues
|
|
$ |
17,016 |
|
|
$ |
10,717 |
|
Total costs and expenses
|
|
|
23,542 |
|
|
|
11,668 |
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
(6,526 |
) |
|
|
(951 |
) |
Miscellaneous income
|
|
|
12 |
|
|
|
1 |
|
Income tax benefit from discontinued operations
|
|
|
(1,190 |
) |
|
|
(230 |
) |
Minority interest in loss from discontinued operations
|
|
|
(2,951 |
) |
|
|
(230 |
) |
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
$ |
(2,373 |
) |
|
$ |
(490 |
) |
|
|
|
|
|
|
|
The following condensed balance sheet data reflects the balances
for discontinued operations at December 31, 2004 and 2003:
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Current assets
|
|
$ |
2,150 |
|
|
$ |
4,565 |
|
Noncurrent assets
|
|
|
3,989 |
|
|
|
8,290 |
|
|
|
|
|
|
|
|
|
Total assets
|
|
|
6,139 |
|
|
|
12,855 |
|
Current liabilities
|
|
|
1,082 |
|
|
|
1,237 |
|
Noncurrent liabilities
|
|
|
196 |
|
|
|
41 |
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
1,278 |
|
|
|
1,278 |
|
Net assets
|
|
$ |
4,861 |
|
|
$ |
11,577 |
|
|
|
|
|
|
|
|
F-74
INDEPENDENT AUDITORS REPORT
Alpha Natural Resources, LLC
and Board of Directors of
Coastal Coal Company, LLC:
We have audited the accompanying consolidated balance sheet of
Coastal Coal Company, LLC and subsidiary (the Company) as of
December 31, 2002, and the related consolidated statements
of operations, changes in members equity and comprehensive
income (loss), and cash flows for the period from
January 1, 2003 to January 31, 2003 and the year ended
December 31, 2002. These consolidated financial statements
are the responsibility of the Companys management. Our
responsibility is to express an opinion on these consolidated
financial statements based on our audits.
We conducted our audits 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 audits provide a
reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred
to above present fairly, in all material respects, the financial
position of Coastal Coal Company, LLC and subsidiary as of
December 31, 2002 and the results of their operations and
their cash flows for the period from January 1, 2003 to
January 31, 2003 and the year ended December 31, 2002,
in conformity with accounting principles generally accepted in
the United States of America.
As discussed in note 1 to the consolidated financial
statements, the Company adopted the provisions of FASB Statement
No. 143, Accounting for Asset Retirement
Obligations, effective January 1, 2003.
/s/ KPMG LLP
Roanoke, Virginia
April 29, 2004
F-75
COASTAL COAL COMPANY, LLC
CONSOLIDATED BALANCE SHEET
December 31, 2002
Assets
|
|
|
|
|
|
|
Current assets:
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
22,250 |
|
|
Accounts receivable, net
|
|
|
33,012,961 |
|
|
Inventories
|
|
|
11,904,110 |
|
|
Prepaid expenses and other current assets
|
|
|
2,396,419 |
|
|
|
|
|
|
|
Total current assets
|
|
|
47,335,740 |
|
Property, plant, and equipment, net
|
|
|
89,988,270 |
|
Other noncurrent assets, net
|
|
|
13,892,542 |
|
|
|
|
|
|
|
Total assets
|
|
$ |
151,216,552 |
|
|
|
|
|
|
Liabilities and Members Equity |
Current liabilities:
|
|
|
|
|
|
Bank overdraft
|
|
$ |
2,744,855 |
|
|
Accounts payable
|
|
|
9,975,516 |
|
|
Accrued payroll
|
|
|
553,268 |
|
|
Other current liabilities
|
|
|
36,954,376 |
|
|
|
|
|
|
|
Total current liabilities
|
|
|
50,228,015 |
|
Other noncurrent liabilities
|
|
|
80,074,583 |
|
|
|
|
|
|
|
Total liabilities
|
|
|
130,302,598 |
|
Minority interest in subsidiary
|
|
|
(703,740 |
) |
Members equity:
|
|
|
|
|
|
Capital contributions
|
|
|
263,971,698 |
|
|
Advances to related parties, net
|
|
|
(28,763,662 |
) |
|
Accumulated other comprehensive loss
|
|
|
(17,284,264 |
) |
|
Accumulated deficit
|
|
|
(196,306,078 |
) |
|
|
|
|
|
|
Total members equity
|
|
|
21,617,694 |
|
Commitments and contingencies
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and members equity
|
|
$ |
151,216,552 |
|
|
|
|
|
See accompanying notes to consolidated financial statements.
F-76
COASTAL COAL COMPANY, LLC
CONSOLIDATED STATEMENTS OF OPERATIONS
Period from January 1, 2003 to January 31, 2003
and
year ended December 31, 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
|
|
January 1, | |
|
|
|
|
2003 to | |
|
Year Ended | |
|
|
January 31, | |
|
December 31, | |
|
|
2003 | |
|
2002 | |
|
|
| |
|
| |
Revenues:
|
|
|
|
|
|
|
|
|
|
Net sales
|
|
$ |
21,501,688 |
|
|
|
269,242,430 |
|
|
Royalty and other
|
|
|
257,335 |
|
|
|
14,325,268 |
|
|
|
|
|
|
|
|
|
|
|
21,759,023 |
|
|
|
283,567,698 |
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
Cost of sales (exclusive of items shown separately below)
|
|
|
18,159,578 |
|
|
|
270,548,861 |
|
|
Depreciation, depletion and amortization
|
|
|
1,150,516 |
|
|
|
15,082,381 |
|
|
Administrative and general (exclusive of depreciation and
amortization shown separately above)
|
|
|
1,092,602 |
|
|
|
11,546,250 |
|
|
|
|
|
|
|
|
|
|
|
20,402,696 |
|
|
|
297,177,492 |
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
1,356,327 |
|
|
|
(13,609,794 |
) |
Gain (loss) on sale of property, plant, and equipment
|
|
|
(15,459 |
) |
|
|
3,460,840 |
|
Interest income (expense), net
|
|
|
(79,508 |
) |
|
|
663,507 |
|
|
|
|
|
|
|
|
|
|
Income (loss) before cumulative effect of accounting change and
minority interest
|
|
|
1,261,360 |
|
|
|
(9,485,447 |
) |
Cumulative effect of accounting change
|
|
|
6,762,081 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before minority interest
|
|
|
8,023,441 |
|
|
|
(9,485,447 |
) |
Minority interest
|
|
|
(32,358 |
) |
|
|
3,454 |
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
7,991,083 |
|
|
|
(9,481,993 |
) |
|
|
|
|
|
|
|
See accompanying notes to consolidated financial statements.
F-77
COASTAL COAL COMPANY, LLC
CONSOLIDATED STATEMENTS OF CHANGES
IN MEMBERS EQUITY AND COMPREHENSIVE INCOME (LOSS)
Period from January 1, 2003 to January 31, 2003
and
year ended December 31, 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated | |
|
|
|
|
|
|
|
|
Advances to | |
|
Other | |
|
|
|
|
|
|
Capital | |
|
(from) Related | |
|
Comprehensive | |
|
Accumulated | |
|
|
|
|
Contributions | |
|
Parties, Net | |
|
Loss | |
|
Deficit | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Balances, December 31, 2001
|
|
$ |
263,971,698 |
|
|
|
39,114,285 |
|
|
|
|
|
|
|
(186,824,085 |
) |
|
|
116,261,898 |
|
Affiliate transactions, net
|
|
|
|
|
|
|
(67,877,947 |
) |
|
|
|
|
|
|
|
|
|
|
(67,877,947 |
) |
Net loss
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(9,481,993 |
) |
|
|
(9,481,993 |
) |
Minimum pension liability adjustment
|
|
|
|
|
|
|
|
|
|
|
(17,284,264 |
) |
|
|
|
|
|
|
(17,284,264 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive loss
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(26,766,257 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2002
|
|
|
263,971,698 |
|
|
|
(28,763,662 |
) |
|
|
(17,284,264 |
) |
|
|
(196,306,078 |
) |
|
|
21,617,694 |
|
Affiliate transactions, net
|
|
|
|
|
|
|
16,309,474 |
|
|
|
|
|
|
|
|
|
|
|
16,309,474 |
|
Net income and comprehensive income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,991,083 |
|
|
|
7,991,083 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, January 31, 2003
|
|
$ |
263,971,698 |
|
|
|
(12,454,188 |
) |
|
|
(17,284,264 |
) |
|
|
(188,314,995 |
) |
|
|
45,918,251 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to consolidated financial statements.
F-78
COASTAL COAL COMPANY, LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS
Period from January 1, 2003 to January 31, 2003
and
year ended December 31, 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
|
|
January 1, | |
|
|
|
|
2003 to | |
|
Year Ended | |
|
|
January 31, | |
|
December 31, | |
|
|
2003 | |
|
2002 | |
|
|
| |
|
| |
Cash flows from operating activities:
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
7,991,083 |
|
|
|
(9,481,993 |
) |
|
Adjustments to reconcile net income (loss) to net cash provided
by (used in) operating activities:
|
|
|
|
|
|
|
|
|
|
|
Cumulative effect of accounting change
|
|
|
(6,762,081 |
) |
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
1,150,516 |
|
|
|
15,082,381 |
|
|
|
Accretion of asset retirement obligation
|
|
|
85,241 |
|
|
|
|
|
|
|
(Gain) loss on sale of property, plant, and equipment
|
|
|
15,459 |
|
|
|
(3,460,840 |
) |
|
|
Amortization of deferred gain on sale of mineral reserves
|
|
|
(24,686 |
) |
|
|
(22,336 |
) |
|
|
Virginia tax credit refundable to parent
|
|
|
(115,801 |
) |
|
|
(1,275,086 |
) |
|
|
Minority interest
|
|
|
32,358 |
|
|
|
(3,454 |
) |
|
|
Increase (decrease) in cash flows from changes in:
|
|
|
|
|
|
|
|
|
|
|
|
Accounts receivable, net
|
|
|
(2,393,076 |
) |
|
|
4,603,307 |
|
|
|
|
Inventories
|
|
|
(87,800 |
) |
|
|
(1,602,775 |
) |
|
|
|
Prepaid expenses and other current assets
|
|
|
581,143 |
|
|
|
(2,357,988 |
) |
|
|
|
Other noncurrent assets
|
|
|
(1,291,346 |
) |
|
|
1,319,539 |
|
|
|
|
Accounts payable
|
|
|
1,131,362 |
|
|
|
(11,194,113 |
) |
|
|
|
Accrued payroll
|
|
|
390,611 |
|
|
|
(500,116 |
) |
|
|
|
Other current liabilities
|
|
|
(14,015,463 |
) |
|
|
17,913,630 |
|
|
|
|
Other noncurrent liabilities
|
|
|
(1,497,539 |
) |
|
|
8,654,774 |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) operating activities
|
|
|
(14,810,019 |
) |
|
|
17,674,930 |
|
|
|
|
|
|
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
Proceeds from sale of property, plant, and equipment
|
|
|
21,300 |
|
|
|
57,000,000 |
|
|
Purchases of property, plant, and equipment
|
|
|
(1,982,298 |
) |
|
|
(5,818,601 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) investing activities
|
|
|
(1,960,998 |
) |
|
|
51,181,399 |
|
|
|
|
|
|
|
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
Advances to related parties, net
|
|
|
16,425,275 |
|
|
|
(66,602,861 |
) |
|
Change in bank overdraft
|
|
|
345,742 |
|
|
|
(2,253,468 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities
|
|
|
16,771,017 |
|
|
|
(68,856,329 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net increase in cash and cash equivalents
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at beginning of period
|
|
|
22,250 |
|
|
|
22,250 |
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$ |
22,250 |
|
|
|
22,250 |
|
|
|
|
|
|
|
|
Supplemental disclosure of cash flow information:
|
|
|
|
|
|
|
|
|
|
Cash paid during the period for interest
|
|
$ |
135,333 |
|
|
|
64,419 |
|
|
Noncash investing and financing activities:
|
|
|
|
|
|
|
|
|
|
|
Deferred gain on sale of mineral reserves
|
|
|
|
|
|
|
7,740,245 |
|
|
|
Deferred gain on sale of real property
|
|
|
|
|
|
|
776,366 |
|
|
|
Minimum pension liability adjustment
|
|
|
|
|
|
|
17,284,264 |
|
See accompanying notes to consolidated financial statements.
F-79
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
January 31, 2003 and December 31, 2002
|
|
(1) |
Summary of Significant Accounting Policies and Practices |
|
|
(a) |
Description of Business |
Coastal Coal Company, LLC and its majority owned subsidiary,
Coastal Coal West Virginia, LLC, (collectively, the
Company) were owned by El Paso CGP Company and American
Natural Resources Company, wholly owned subsidiaries of
El Paso Corporation (El Paso) through January 31,
2003 (see note 13). The Company is organized as a limited
liability company under the laws of the state of Delaware. The
Company is engaged in the business of extracting coal from
reserves located in Virginia, West Virginia, and Kentucky, and
leasing land and associated mineral reserves to coal mining
companies. Coal extracted by the Company is primarily sold to
utility companies located in the East and Southeast regions of
the United States of America.
|
|
(b) |
Principles of Consolidation |
The consolidated financial statements include the following
companies.
Companies with coal reserves and production facilities:
|
|
|
|
|
Brooks Run Mining Company |
|
|
|
Enterprise Mining Company |
|
|
|
Virginia Iron, Coal and Coke (VICC) Mining Company |
|
|
|
Kingwood Mining Company |
|
|
|
Greenbrier Mining Company (Inactive) |
Companies providing administrative services:
|
|
|
|
|
Coastal Coal Administration |
|
|
|
Coastal Coal Sales Company |
Holding companies:
|
|
|
|
|
Coastal Coal Company, LLC |
|
|
|
Coastal Coal-West Virginia, LLC |
All significant intercompany balances and transactions have been
eliminated in consolidation.
|
|
(c) |
Cash and Cash Equivalents |
Cash and cash equivalents consist of cash on hand, cash in
banks, and investments in money market accounts and are stated
at cost, which approximates fair market value. The Company
considers all highly liquid debt instruments with original
maturities of three months or less to be cash equivalents.
|
|
(d) |
Accounts Receivable and Allowance for Doubtful
Accounts |
Trade accounts receivable are recorded at the invoiced amount
and do not bear interest. The allowance for doubtful accounts is
the Companys best estimate of the amount of probable
credit losses in the Companys existing accounts
receivable. The allowance for doubtful accounts consists of an
amount for specifically identified uncollectable accounts and a
general allowance based on historical losses for all accounts.
The Company does not have any off-balance-sheet credit exposure
related to its customers.
F-80
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Coal inventory is stated at the lower of cost, with cost
determined using the average monthly production costs, or net
realizable value. Purchased coal is stated at purchase price.
Coal inventory at December 31, 2002 was comprised of raw,
processed, and purchased coal.
Supplies inventory is stated at the lower of average cost or net
market value.
|
|
(f) |
Property, Plant, and Equipment |
Property, plant, and equipment are stated at cost. Expenditures
for maintenance and repairs, which do not improve or extend the
lives of the related assets, are charged to expense as incurred
while major renewals and betterments are capitalized. Upon
retirement or sale of an asset, its cost and related accumulated
depreciation or amortization are removed from the property
accounts. Depreciation of plant and equipment for financial
reporting purposes is provided using the straight-line method
over the assets estimated useful lives.
Costs incurred as part of the acquisition of mineral interests
and mine development costs incurred to expand capacity of
operating mines or to develop new mines are capitalized and
charged to operations on the units-of-production method. Mine
development costs include costs incurred for site preparation
and development at the mines during the development stage.
|
|
(g) |
Impairment of Long-Lived Assets |
Statement of Financial Accounting Standards
(SFAS) No. 144, Accounting for the Impairment or
Disposal of Long-Lived Assets, provides a single accounting
model for long-lived assets to be disposed of.
SFAS No. 144 also changes the criteria for classifying
an asset as held for sale; and broadens the scope of businesses
to be disposed of that quality for reporting as discontinued
operations and changes the timing of recognizing losses on such
operations. The Company adopted SFAS No. 144 on
January 1, 2002.
In accordance with SFAS No. 144, long-lived assets,
such as property, plant, and equipment, and purchased
intangibles subject to amortization, are reviewed for impairment
whenever events or changes in circumstances indicate that the
carrying amount of an asset may not be recoverable.
Recoverability of assets to be held and used is measured by a
comparison of the carrying amount of an asset to estimated
undiscounted future cash flows expected to be generated by the
asset. If the carrying amount of an asset exceeds its estimated
future cash flows, an impairment charge is recognized by the
amount by which the carrying amount of the asset exceeds the
fair value of the asset. Assets to be disposed of would be
separately presented in the balance sheet and reported at the
lower of the carrying amount or fair value less costs to sell,
and are no longer depreciated. The assets and liabilities of a
disposal group classified as held for sale would be presented
separately in the appropriate asset and liability sections of
the balance sheet.
Prior to the adoption of SFAS No. 144, the Company
accounted for long-lived assets in accordance with
SFAS No. 121, Accounting for Impairment of
Long-Lived Assets and for Long-Lived Assets to be Disposed
Of.
The Company has future obligations to reclaim properties
disturbed in conjunction with coal operations under federal and
state laws. Reclamation of disturbed acreage is performed as a
normal part of the mining process. The Company adopted
SFAS No. 143, Accounting for Asset Retirement
Obligations, on January 1, 2003. The Companys
liability for reclamation at January 31, 2003 represents
the fair value of its asset retirement obligation as of this
date. The asset retirement obligation will be adjusted in the
F-81
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
future to reflect the passage of time and changes, if any, in
the estimated future cash flows underlying the initial fair
value measurement. Upon adoption, impacted financial statement
line items were property, plant, and equipment, net; other
current liabilities; other noncurrent liabilities; and the net
cumulative effect of the change in accounting principle.
Property, plant, and equipment, net increased by $2,125,877;
other current liabilities decreased by $2,524,368; other
noncurrent liabilities decreased by $2,111,836; and the
cumulative effect of the accounting change of $6,762,081 was
reflected in the consolidated statement of income for the period
from January 1, 2003 to January 31, 2003.
Prior to the adoption of SFAS No. 143, expenditures
relating to environmental regulatory requirements and
reclamation costs undertaken during mine operations were charged
against earnings as incurred. Estimated site restoration and
post closure reclamation costs were charged against earnings
using the unit-of-production method over the expected economic
life of each mine. Accrued reclamation costs were subject to
review by management on a regular basis and were revised when
appropriate for changes in future estimated costs and/or
regulatory requirements.
|
|
(i) |
Advance Mining Royalties |
Leases, which require minimum annual or advance payments and are
recoverable from future production, are generally deferred and
charged to expense as the coal is subsequently produced. At
December 31, 2002, advance mining royalties totaled
approximately $7.8 million, of which approximately
$1.7 million is included in prepaid expenses and other
current assets. The Company periodically assesses the
recoverability of such prepaid minimum royalties based on
current operating plans, expiration dates of such prepaid
royalties, and the economic environment in the coal industry,
and records a charge to earnings when it is deemed more likely
than not that such amounts will not be recovered.
|
|
(j) |
Postretirement Benefits Other Than Pensions |
Postretirement benefits other than pensions are accounted for in
accordance with SFAS No. 106, Employers
Accounting for Postretirement Benefits Other Than Pensions.
SFAS No. 106 requires employers to accrue the cost of
postretirement benefits during the employees service and
over the average remaining life expectancy of inactive
participants.
Coal mining companies are obligated to pay coal workers
pneumoconiosis (black lung) benefits to eligible recipients with
respect to claims awarded on or after July 1, 1973. The
liability and annual expense for these benefits are based on
annual evaluations prepared by the Companys independent
actuaries.
The Company has a noncontributory pension plan covering
substantially all employees. Costs of the plan are charged to
current operations and are based on various actuarial
assumptions.
|
|
(m) |
Health Insurance Programs |
The Company is self-insured, up to specified limits, for costs
of casualty claims and medical claims. The Company utilizes
commercial insurance to cover what it considers significant or
catastrophic casualty and medical claims. Accrued casualty
losses are based on actuarial assumptions, adjusted for Company
specific history and expectations.
F-82
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
The Company currently derives the majority of its revenue from
the sale of coal and leasing of land and related mineral
reserves to coal mining companies. Revenue derived from the sale
of coal is recognized at the time of shipment or delivery to the
customer, and the customer takes ownership and assumes risk of
loss based on shipping terms. Revenue derived from the mineral
leases are recognized at the time coal is extracted from the
leased premises.
Shipping and handling costs paid to third-party carriers are
recorded as freight expense and included in cost of sales.
The Company is a limited liability company organized under the
laws of the State of Delaware. Tax attributes of a limited
liability company pass through to the individual investors.
Accordingly, the accompanying consolidated balance sheet does
not include income tax assets or liabilities.
|
|
(q) |
Fair Value of Financial Instruments |
The carrying amounts reported in the consolidated balance sheet
for cash and cash equivalents, bank overdraft, accounts
receivable, and accounts payable approximate fair value because
of the short maturity of these instruments. See note 10
regarding advances to related parties.
The preparation of financial statements in conformity with
accounting principles generally accepted in the United States of
America requires management to make estimates and assumptions
that affect the reported amounts of assets and liabilities and
the disclosure of contingent assets and liabilities at the
balance sheet date, and the reported amounts of revenues and
expenses during the reporting period. Significant estimates and
assumptions made by the Company include the allowance for
doubtful accounts; recoverable mineral tonnage in the ground;
pension and postretirement accruals; reclamation and mine
closure obligations; black lung and workers compensation
liabilities; and inventory obsolescence. Actual results could
differ from those estimates.
Accounts receivable, net at December 31, 2002 consists of
the following:
|
|
|
|
|
Trade accounts receivable, net of allowance for doubtful
accounts of $7,772
|
|
$ |
19,544,968 |
|
Land mineral lease royalties
|
|
|
485,457 |
|
Black lung excise tax refund receivable
|
|
|
10,017,692 |
|
Other
|
|
|
2,964,844 |
|
|
|
|
|
|
|
$ |
33,012,961 |
|
|
|
|
|
Land and mineral lease royalties receivable represent amounts
currently due from third parties for coal mined from Company
reserves. The black lung excise tax refund receivable represents
claims, including interest, due from the Internal Revenue
Service for a refund of excise taxes paid on export coal
shipments made by the Company for the period 1994 through 2000.
F-83
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Inventories at December 31, 2002 consists of the following:
|
|
|
|
|
Coal
|
|
$ |
8,284,715 |
|
Mining supplies
|
|
|
3,619,395 |
|
|
|
|
|
|
|
$ |
11,904,110 |
|
|
|
|
|
(4) Property, Plant, and Equipment
Property, plant, and equipment at December 31, 2002
consists of the following:
|
|
|
|
|
|
|
|
|
|
|
Estimated | |
|
|
|
|
Lives | |
|
|
|
|
| |
|
|
Land and mineral rights
|
|
|
|
|
|
$ |
14,463,803 |
|
Plant, equipment, and mine development
|
|
|
3-30 years |
|
|
|
219,388,767 |
|
Construction in progress
|
|
|
|
|
|
|
7,037,769 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
240,890,339 |
|
Less accumulated depreciation, depletion, and amortization
|
|
|
|
|
|
|
150,902,069 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
89,988,270 |
|
|
|
|
|
|
|
|
In fiscal 2001, as a result of changes occurring in the energy
industry, the Company assessed the carrying values of property,
plant, and equipment and determined that the carrying amounts of
certain of its assets were impaired. As a result, the Company
reduced historical carrying values of certain of its property,
plant and equipment to their estimated fair market values. The
impairment charge recorded totaled approximately
$127.6 million.
|
|
(5) |
Employees Termination Benefits |
Between March and June of 2002, the Company approved a plan to
terminate approximately 100 coal-mining and administrative
employees located in Virginia and Kentucky. As compensation for
their termination, the Company offered terminated employees a
benefits package based upon the employees years of service
and levels of income. Approximately $70,000 and
$3.3 million of such benefits expense was incurred for the
period from January 1, 2003 to January 31, 2003 and
the year ended December 31, 2002, respectively.
Approximately $528,000 was unpaid at December 31, 2002 and
is included in other current liabilities.
F-84
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
|
|
(6) |
Other Current and Noncurrent Liabilities |
Other current and noncurrent liabilities at December 31,
2002 comprise the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current | |
|
Noncurrent | |
|
Total | |
|
|
| |
|
| |
|
| |
Black lung and other workers compensation obligations
|
|
$ |
3,100,000 |
|
|
|
31,300,182 |
|
|
|
34,400,182 |
|
Accrued reclamation costs
|
|
|
1,000,000 |
|
|
|
14,329,905 |
|
|
|
15,329,905 |
|
Pension benefits
|
|
|
2,682,134 |
|
|
|
5,974,419 |
|
|
|
8,656,553 |
|
Postretirement benefits
|
|
|
826,000 |
|
|
|
13,495,000 |
|
|
|
14,321,000 |
|
Long-term disability benefits
|
|
|
1,900,000 |
|
|
|
4,881,000 |
|
|
|
6,781,000 |
|
Deferred gain on sale of coal reserves
|
|
|
324,838 |
|
|
|
7,393,071 |
|
|
|
7,717,909 |
|
Accrued settlement loss on contract
|
|
|
16,062,717 |
|
|
|
|
|
|
|
16,062,717 |
|
Black lung excise tax refund liabilities
|
|
|
6,017,714 |
|
|
|
1,744,640 |
|
|
|
7,762,354 |
|
Accrued other taxes
|
|
|
4,114,670 |
|
|
|
|
|
|
|
4,114,670 |
|
Other
|
|
|
926,303 |
|
|
|
956,366 |
|
|
|
1,882,669 |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
36,954,376 |
|
|
|
80,074,583 |
|
|
|
117,028,959 |
|
|
|
|
|
|
|
|
|
|
|
In connection with services rendered in obtaining the black lung
excise tax refund (see note 2), the Company has agreed to
pay portions of the refund to certain third parties. This amount
is included in current and noncurrent liabilities.
Under the Federal Surface Mining Control and Reclamation Act of
1977 and similar state statutes, mine property is required to be
restored in accordance with regulated standards. The
establishment of the reclamation liability is based on permit
requirements and requires various estimates and assumptions,
principally associated with costs and timing of expenditures.
The Company periodically reviews its entire environmental
liability and makes necessary adjustments, including permit
changes, revisions to costs and timing of expenditures to
reflect current experience.
As described in note 1, the Company adopted the provisions
of SFAS No. 143 on January 1, 2003. The changes
in the asset retirement obligation for the period from
January 1, 2003 to January 31, 2003 are as follows:
|
|
|
|
|
|
Reclamation liability at December 31, 2002
|
|
$ |
15,329,905 |
|
Cumulative effect of accounting change
|
|
|
(6,762,081 |
) |
|
|
|
|
|
Asset retirement obligation at January 1, 2003
|
|
|
8,567,824 |
|
Accretion from January 1, 2003 to January 31, 2003
|
|
|
85,241 |
|
Sites added from January 1, 2003 to January 31, 2003
|
|
|
928,861 |
|
|
|
|
|
|
Asset retirement obligation at January 31, 2003
|
|
$ |
9,581,926 |
|
|
|
|
|
The Company leases coal properties to independent third parties
under terms requiring periodic minimum royalty payments. These
payments are recorded by the Company as deferred royalty income
when received and are recognized into income using the units of
production method associated with specific reserves covered
under the lease. At December 31, 2002, the Company has
approximately $223,000 of deferred royalty income to be
recognized in future periods, which is included in other current
liabilities.
On December 4, 2002, the Company sold the majority of the
coal properties of three of its subsidiaries, Enterprise,
Kingwood and VICC, to CSTL, LLC for $57 million. As part of
this sale, the
F-85
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
Companys then parent company, El Paso, received the
right to receive an overriding royalty on the coal produced from
the assets sold. The majority of the coal properties were leased
back to the Company. The total gain was approximately
$11.2 million. The Company has deferred the gain on the
sale of the coal properties amounting to approximately
$7.7 million as of December 31, 2002, of which
approximately $325,000 is included in other current liabilities.
The Company had a long-term supply contract with American
Electric Power (AEP) at a below market price. The terms of the
contract were for 1.2 million tons annually until
June 30, 2005. On December 9, 2002, the Company
entered into a termination and release agreement, whereby AEP
agreed to terminate its contract with the Company and release
the Company from any further obligations under the supply
agreement in exchange for a settlement payment of approximately
$16.1 million. This amount was recorded as a loss during
2002 and is included in other current liabilities in the
consolidated balance sheet as of December 31, 2002.
|
|
(7) |
Virginia Coalfield Employment Enhancement Tax Credit |
For tax years 1996 though 2007, Virginia companies with an
economic interest in coal, earn tax credits based upon tons
sold, seam thickness, and employment levels. The maximum credit
earned equals $0.40 per ton for surface mined coal and
$1.00 or $2.00 per ton for deep mined coal depending on
seam thickness. Credits allowable are deducted from the maximum
amounts if employment levels are not maintained from the
previous year, and no credit is allowed for coal sold to
Virginia utilities. Currently, the cash benefit of the credit is
realized between three and four years after being earned and
either offsets taxes imposed by Virginia at 100% or is
refundable by the state at 85% of the face value to the extent
taxes are not owed. The credits are available or refundable to
El Paso. The Company records the present value of the
credit as a reduction of current year operating costs and as an
adjustment to due from related parties as it is earned. The
reduction to operating costs for the period from January 1,
2003 to January 31, 2003, and for the year ended
December 31, 2002 was approximately $116,000 and
$1.3 million, respectively.
|
|
(8) |
Workers Compensation and Pneumoconiosis Benefit
Obligations |
Coal mining companies are subject to the Federal Coal Mine
Health and Safety Act of 1969 (the Act), as amended, and various
states statutes for the payment of medical and disability
benefits to eligible recipients related to coal workers
pneumoconiosis (black lung). The Company provides for these
claims principally through a self-insurance program. The
liability for such claims is determined based upon an annual
evaluation prepared by the Companys independent actuaries.
On December 20, 2000, the United States Department of Labor
published revised administrative rules with respect to the Act.
The revised regulations are expected to increase the cost of
benefits paid under the Act by generating an increase to the
approval rate of claims filed under the Act as well as an
increase to the average cost per claim filed under the Act. The
Companys black lung reserves incorporate an estimate of
the increase in the frequency and severity of black lung claims
due to the Department of Labors revised administrative
rules. However, due to lack of historical data with regards to
the effect of the revised administrative rules, it is possible
that actual results may materially differ from the estimate
provided above.
|
|
(9) |
Pension, Postretirement, and Postemployment Benefits |
The Company has a defined benefit pension plan covering
substantially all employees which provides for retirement
benefits based upon an employees credited service at
termination and, for salaried employees, compensation history.
Funding for the plan is based upon a review of the specific
requirements and an evaluation of the assets and liabilities of
the plan.
F-86
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
In addition to the Companys defined benefit pension plan,
the Company also sponsors a defined benefit health care plan.
The plan provides certain medical, dental and life insurance
benefits to eligible retired employees. Employees of the Company
generally become eligible for retiree health care benefits by
retiring from the Company after reaching ages 50 or 55,
depending upon the nature of their service to the Company, and
attaining ten years of service. Generally, the medical and
dental plans pay a stated percentage of most medical expenses
reduced for any deductibles and payments made by government
programs and other group coverage. The postretirement medical,
dental and life insurance plans are unfunded. The measurement
date used to determine pension and postretirement benefit
measures is September 30.
The net periodic benefit cost for the period from
January 1, 2003 to January 31, 2003 is as follows:
|
|
|
|
|
|
|
|
|
|
|
Period from January 1, | |
|
|
2003 to January 31, 2003 | |
|
|
| |
|
|
Pension | |
|
Postretirement | |
|
|
Benefits | |
|
Benefits | |
|
|
| |
|
| |
Net periodic benefit cost
|
|
$ |
70,572 |
|
|
|
175,000 |
|
|
|
|
|
|
|
|
The components of the change in benefit obligations and net
periodic benefit cost for the year ended December 31, 2002
are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2002 | |
|
|
| |
|
|
Pension | |
|
Postretirement | |
|
|
Benefits | |
|
Benefits | |
|
|
| |
|
| |
Change in benefit obligation:
|
|
|
|
|
|
|
|
|
|
Pension/ Postretirement benefit obligation at beginning of year
|
|
$ |
53,555,551 |
|
|
|
14,534,000 |
|
|
Service cost
|
|
|
3,028,948 |
|
|
|
|
|
|
Interest cost
|
|
|
3,922,028 |
|
|
|
1,371,000 |
|
|
Benefits paid
|
|
|
(2,682,134 |
) |
|
|
(1,584,000 |
) |
|
Actuarial loss
|
|
|
10,633,556 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Benefit obligation end of year
|
|
$ |
68,457,949 |
|
|
|
14,321,000 |
|
|
|
|
|
|
|
|
Change in plan assets:
|
|
|
|
|
|
|
|
|
|
Fair value of plan assets at beginning of year
|
|
$ |
60,153,390 |
|
|
|
|
|
|
Return on assets actual
|
|
|
(6,350,688 |
) |
|
|
|
|
|
Benefits paid
|
|
|
(2,682,134 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair value of plan assets at end of year
|
|
$ |
51,120,568 |
|
|
|
|
|
|
|
|
|
|
|
|
F-87
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2002 | |
|
|
| |
|
|
Pension | |
|
Postretirement | |
|
|
Benefits | |
|
Benefits | |
|
|
| |
|
| |
Actuarial present value of accumulated benefit obligation
|
|
$ |
(68,457,949 |
) |
|
|
(14,321,000 |
) |
Plan assets at fair value
|
|
|
51,120,568 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Unfunded benefit obligation
|
|
|
(17,337,381 |
) |
|
|
(14,321,000 |
) |
Unrecognized net actuarial (gain) loss
|
|
|
25,965,092 |
|
|
|
|
|
Unrecognized prior service cost
|
|
|
1,093,252 |
|
|
|
|
|
Contributions
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net amount recognized at year end
|
|
$ |
9,720,963 |
|
|
|
(14,321,000 |
) |
|
|
|
|
|
|
|
Amounts included in balance sheet:
|
|
|
|
|
|
|
|
|
|
Accrued benefit cost
|
|
$ |
(8,656,553 |
) |
|
|
(14,321,000 |
) |
|
Intangible asset
|
|
|
1,093,252 |
|
|
|
|
|
|
Change in additional minimum liability obligation
|
|
|
17,284,264 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net amount recognized at year end
|
|
$ |
9,720,963 |
|
|
|
(14,321,000 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended | |
|
|
December 31, 2002 | |
|
|
| |
|
|
Pension | |
|
Postretirement | |
|
|
Benefits | |
|
Benefits | |
|
|
| |
|
| |
Components of net periodic benefit cost:
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$ |
3,028,948 |
|
|
|
|
|
|
Interest cost on Projected Benefit Obligation (PBO)
|
|
|
3,922,028 |
|
|
|
1,371,000 |
|
|
Return on assets expected
|
|
|
(5,956,703 |
) |
|
|
|
|
|
Other amortization, net
|
|
|
75,613 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic benefit cost
|
|
$ |
1,069,886 |
|
|
|
1,371,000 |
|
|
|
|
|
|
|
|
Weighted average actuarial assumptions at December 31, 2002:
|
|
|
|
|
|
|
|
|
|
Discount rate
|
|
|
6.75 |
% |
|
|
6.75 |
% |
|
Expected long-term rate of return on plan assets
|
|
|
8.80 |
% |
|
|
|
|
|
Rate of compensation increase
|
|
|
4.00 |
% |
|
|
|
|
The weighted average annual rate of increase in the per capita
cost of covered benefits (i.e., health care trend rate) for
medical benefits is 9.0% in 2002, decreasing to 6.0% in 2008 and
thereafter.
The Company also provides long-term disability benefits for
substantially all employees. The Company provides for these
claims principally through a self-insurance program. The
liability for such claims is determined based upon an annual
evaluation by the Companys independent actuaries. As of
December 31, 2002, an accrued benefit liability of
$6,781,000 is recorded for these postemployment benefits.
F-88
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
The measurement date used to determine postemployment benefit
measures is January 1. Assumptions used by the Companys
independent actuaries in determining the long-term disability
liability for 2002 included the following:
|
|
|
Discount rate
|
|
7.25% |
Mortality healthy
|
|
1983 Group Annuity Mortality Table |
Mortality disabled
|
|
1987 Commissioners Group Long-Term Disability Valuation
Table |
Annual Health Care Cost Trend Rate
|
|
9.0% for 2002 declining to 6.0% by 2008 |
El Paso has a defined contribution employee benefit plan
(the Plan) covering substantially all employees of the Company.
The Plan is subject to the provisions of the Employee Retirement
Income Security Act of 1974, as amended. A participant may elect
to make basic contributions from 2% to 15% of his or her
eligible compensation on a before-tax or after-tax basis.
El Paso made matching contributions on behalf of the
Company in cash equal to 75% of a participants basic
contribution up to a maximum level of 6% of eligible
compensation. Those contributions were approximately $100,000
for the period from January 1, 2003 to January 31,
2003 and $1.3 million for the year ended December 31,
2002.
|
|
(10) |
Related Party Transactions |
Affiliates of El Paso perform certain administrative
services for the Company and allocate charges based on the
services performed. Such administrative services include, but
are not limited to, finance, treasury, cash management, payroll
processing, employee benefit administration and certain
accounting functions. El Paso would also advance cash to
the Company, on an as needed basis, to fund the Companys
payroll, accounts payable and other cash needs, and would borrow
any excess cash generated by the Company. As of
December 31, 2002, El Paso and its affiliates owe the
Company approximately $28.8 million related to these
matters, the amount being reflected as a component of
members equity.
|
|
(11) |
Commitments and Contingencies |
The Company mines coal on properties leased from independent
third parties. Under the terms of the leases, the Company pays
production royalties based on a percentage of the net sales
price of coal produced or based on the actual tonnage mined from
the leased premises. The Companys mineral leases require
the Company to pay minimum royalties. Some of such leases have
fixed terms and others are effective until exhaustion of the
mineral reserves. Future minimum royalty payments under mineral
lease agreements at December 31, 2002 were as follows:
|
|
|
|
|
|
Year Ending |
|
Royalty | |
December 31, |
|
Commitments | |
|
|
| |
2003
|
|
$ |
4,373,138 |
|
2004
|
|
|
4,170,948 |
|
2005
|
|
|
3,661,676 |
|
2006
|
|
|
3,488,176 |
|
2007
|
|
|
3,488,176 |
|
Thereafter
|
|
|
17,064,480 |
|
|
|
|
|
|
Total
|
|
$ |
36,246,594 |
|
|
|
|
|
The Company is the subject of, or a party to, various suits and
pending or threatened litigation involving governmental agencies
and private interests. Also, the Companys operations are
affected by federal, state, and local laws and regulations
regarding environmental matters and other aspects of its
F-89
COASTAL COAL COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Continued)
business. The outcome or timing of current legal or
environmental matters or the impact, if any, of pending
legislation or regulatory developments on future operations is
not currently estimable.
In the normal course of operations, the Company enters into
long-term supply contracts for the sale of various qualities of
coal to customers in the energy industry. Under the terms of
these contracts, the Company is obligated to supply coal to
customers at prices ranging from approximately $24 to
$38 per ton/, with such prices subject to adjustment in
future periods based upon factors such as the quality of the
coal. All supply contracts entered into as of December 31,
2002 will expire through September 10, 2010.
|
|
(12) |
Risks and Uncertainties |
The Company is engaged in the production of high-quality low
sulfur steam coal for the electric generating industry as well
as industrial customers. Coal produced from the Companys
reserves located in Virginia, West Virginia and Kentucky is
primarily sold to energy companies in the eastern and
southeastern United States under long-term supply agreements.
Additional production from Company reserves not covered under
supply contracts is sold on the open market. The Company is
subject to risks and uncertainties related to the
creditworthiness of customers in the energy industry as well as
price, supply, demand, and other volatility associated with coal
commodity markets. Commodities markets and economic conditions
have been volatile in the past and can be expected to be
volatile in the future.
Three of the Companys largest customers, Mirant Americas
Energy Marketing, LP, South Carolina Electric & Gas and
American Electric Power, account for approximately 17%, 11% and
11%, respectively, of the Companys trade accounts
receivable at December 31, 2002. The Company has
approximately $3.4 million, $2.1 million and
$2.1 million due from Mirant Americas Energy Marketing, LP,
South Carolina Electric & Gas and American Electric
Power, respectively, at December 31, 2002.
Three of the Companys largest customers, Mirant Americas
Energy Marketing, LP, Georgia Power Company, and Ontario Power
Generation account for approximately 20%, 13% and 10%,
respectively, which represents approximately $4.4 million,
$2.9 million and $2.1 million, respectively, of the
Companys net sales for the period from January 1,
2003 to January 31, 2003.
Three of the Companys largest customers, Georgia Power
Company, Ontario Power Generation, and American Electric Power,
account for approximately 16%, 10% and 10%, respectively, which
represents approximately $42.3 million, $27.0 million
and $27.2 million, respectively, of the Companys net
sales for the year ended December 31, 2002.
|
|
(13) |
Subsequent Sale of the Company |
On January 31, 2003, El Paso Corporation sold its
membership interest in the Company, subject to certain retained
assets and liabilities, to AMFIRE, LLC, a subsidiary of Alpha
Natural Resources, LLC. The retained assets and liabilities
included cash, black lung excise tax receivables, pension and
post-employment obligations, black lung obligations, and
workers compensation obligations.
F-90
INDEPENDENT AUDITORS REPORT
Alpha Natural Resources, LLC
and Members, Stockholders, and Partners of
Pennsylvania Entities of Mears Enterprises, Inc.:
We have audited the accompanying combined balance sheets of The
Combined Pennsylvania Entities of Mears Enterprises, Inc. (the
Company) as of December 31, 2002 and 2001 and the related
combined statements of income, stockholders equity and
partners capital, and cash flows for the period
January 1, 2003 to November 17, 2003 and years ended
December 31, 2002 and 2001. These financial statements are
the responsibility of the Companys management. Our
responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits 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 audits provide a reasonable
basis for our opinion.
In our opinion, the combined financial statements referred to
above present fairly, in all material respects, the financial
position of the Company as of December 31, 2002 and 2001
and the results of their operations and cash flows for the
period January 1, 2003 to November 17, 2003 and years
ended December 31, 2002 and 2001 in conformity with
accounting principles generally accepted in the United States of
America.
As discussed in note 2 to the combined financial
statements, the Company adopted the provisions of FASB Statement
No. 143, Accounting for Asset Retirement
Obligations, effective January 1, 2003.
/s/ KPMG LLP
Pittsburgh, Pennsylvania
March 17, 2004
F-91
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
COMBINED BALANCE SHEETS
December 31, 2002 and 2001
|
|
|
|
|
|
|
|
|
|
|
|
|
2002 | |
|
2001 | |
|
|
| |
|
| |
ASSETS |
Current assets:
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
16,890,439 |
|
|
|
12,454,191 |
|
|
Trade accounts receivable
|
|
|
5,555,181 |
|
|
|
5,369,221 |
|
|
Coal inventory
|
|
|
426,323 |
|
|
|
687,582 |
|
|
Prepaid expenses
|
|
|
39,813 |
|
|
|
41,248 |
|
|
Licenses
|
|
|
17,577 |
|
|
|
16,750 |
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
22,929,333 |
|
|
|
18,568,992 |
|
Property, plant, and equipment, net
|
|
|
5,543,343 |
|
|
|
4,875,673 |
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
28,472,676 |
|
|
|
23,444,665 |
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY AND PARTNERS
CAPITAL |
Current liabilities:
|
|
|
|
|
|
|
|
|
|
Trade accounts payable
|
|
$ |
1,646,494 |
|
|
|
2,597,430 |
|
|
Accrued expenses
|
|
|
792,908 |
|
|
|
754,474 |
|
|
Due to related parties
|
|
|
202,049 |
|
|
|
|
|
|
Capital lease obligations current portion
|
|
|
374,718 |
|
|
|
234,497 |
|
|
Other current liabilities
|
|
|
180,017 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
3,196,186 |
|
|
|
3,586,401 |
|
Long-term liabilities:
|
|
|
|
|
|
|
|
|
|
Capital lease obligations long-term
|
|
|
60,712 |
|
|
|
165,137 |
|
|
Asset retirement obligations
|
|
|
1,018,490 |
|
|
|
1,068,796 |
|
|
Due to related parties
|
|
|
|
|
|
|
273,735 |
|
|
Other long-term liabilities
|
|
|
|
|
|
|
28,927 |
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
4,275,388 |
|
|
|
5,122,996 |
|
|
|
|
|
|
|
|
Stockholders equity and partners capital:
|
|
|
|
|
|
|
|
|
|
Common stock, no par or stated value; issued and outstanding
870 shares
|
|
|
38,259 |
|
|
|
38,259 |
|
|
Retained earnings
|
|
|
3,966,562 |
|
|
|
3,584,170 |
|
|
Partners capital
|
|
|
20,192,467 |
|
|
|
14,699,240 |
|
|
|
|
|
|
|
|
|
|
Total stockholders equity and partners capital
|
|
|
24,197,288 |
|
|
|
18,321,669 |
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity and
partners capital
|
|
$ |
28,472,676 |
|
|
|
23,444,665 |
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-92
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
COMBINED STATEMENTS OF INCOME
Period from January 1, 2003 to November 17, 2003
and
years ended December 31, 2002 and 2001
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
|
|
January 1, 2003 | |
|
Year Ended December 31 | |
|
|
to | |
|
| |
|
|
November 17, 2003 | |
|
2002 | |
|
2001 | |
|
|
| |
|
| |
|
| |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal sales
|
|
$ |
45,829,444 |
|
|
$ |
44,459,196 |
|
|
$ |
42,085,943 |
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales and other operating expenses (exclusive of items
shown separately below)
|
|
|
25,480,439 |
|
|
|
22,322,677 |
|
|
|
23,425,162 |
|
|
Depreciation, depletion, and amortization
|
|
|
872,213 |
|
|
|
737,778 |
|
|
|
549,307 |
|
|
Selling and administrative expenses (exclusive of depreciation
and amortization shown separately above)
|
|
|
3,831,639 |
|
|
|
4,175,759 |
|
|
|
2,753,574 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total expenses
|
|
|
30,184,291 |
|
|
|
27,236,214 |
|
|
|
26,728,043 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating profit
|
|
|
15,645,153 |
|
|
|
17,222,982 |
|
|
|
15,357,900 |
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
194,474 |
|
|
|
214,053 |
|
|
|
171,817 |
|
|
Interest expense
|
|
|
(21,705 |
) |
|
|
(36,110 |
) |
|
|
(27,375 |
) |
|
Rental income
|
|
|
598 |
|
|
|
|
|
|
|
19,216 |
|
|
Other income
|
|
|
446,050 |
|
|
|
82,071 |
|
|
|
1,018,035 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income
|
|
|
619,417 |
|
|
|
260,014 |
|
|
|
1,181,693 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before cumulative effect of accounting change
|
|
|
16,264,570 |
|
|
|
17,482,996 |
|
|
|
16,539,593 |
|
Cumulative effect of accounting change (note 2)
|
|
|
(310,855 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
15,953,715 |
|
|
$ |
17,482,996 |
|
|
$ |
16,539,593 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-93
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
COMBINED STATEMENTS OF STOCKHOLDERS EQUITY AND
PARTNERS CAPITAL
Period from January 1, 2003 to November 17, 2003
and
years ended December 31, 2002 and 2001
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders capital accounts | |
|
|
|
|
|
|
| |
|
Total | |
|
|
|
|
|
|
Total | |
|
stockholders | |
|
|
Partners | |
|
Common | |
|
Retained | |
|
stockholders | |
|
equity and | |
|
|
capital | |
|
stock | |
|
earnings | |
|
equity | |
|
partners capital | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Balances, January 1, 2001
|
|
$ |
8,097,360 |
|
|
|
38,259 |
|
|
|
2,225,410 |
|
|
|
2,263,669 |
|
|
|
10,361,029 |
|
Net income
|
|
|
13,166,130 |
|
|
|
|
|
|
|
3,373,463 |
|
|
|
3,373,463 |
|
|
|
16,539,593 |
|
Distributions
|
|
|
(6,564,250 |
) |
|
|
|
|
|
|
(2,014,703 |
) |
|
|
(2,014,703 |
) |
|
|
(8,578,953 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2001
|
|
|
14,699,240 |
|
|
|
38,259 |
|
|
|
3,584,170 |
|
|
|
3,622,429 |
|
|
|
18,321,669 |
|
Net income
|
|
|
16,527,383 |
|
|
|
|
|
|
|
955,613 |
|
|
|
955,613 |
|
|
|
17,482,996 |
|
Distributions
|
|
|
(11,034,156 |
) |
|
|
|
|
|
|
(573,221 |
) |
|
|
(573,221 |
) |
|
|
(11,607,377 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2002
|
|
|
20,192,467 |
|
|
|
38,259 |
|
|
|
3,966,562 |
|
|
|
4,004,821 |
|
|
|
24,197,288 |
|
Net income (loss) January 1, 2003
November 17, 2003
|
|
|
17,327,699 |
|
|
|
|
|
|
|
(1,373,984 |
) |
|
|
(1,373,984 |
) |
|
|
15,953,715 |
|
Distributions
|
|
|
(15,884,156 |
) |
|
|
|
|
|
|
(979,631 |
) |
|
|
(979,631 |
) |
|
|
(16,863,787 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, November 17, 2003
|
|
$ |
21,636,010 |
|
|
|
38,259 |
|
|
|
1,612,947 |
|
|
|
1,651,206 |
|
|
|
23,287,216 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-94
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
COMBINED STATEMENTS OF CASH FLOWS
Period from January 1, 2003 to November 17, 2003
and
years ended December 31, 2002 and 2001
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
Year Ended December 31 | |
|
|
January 1, 2003 to | |
|
| |
|
|
November 17, 2003 | |
|
2002 | |
|
2001 | |
|
|
| |
|
| |
|
| |
Cash flows from operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
15,953,715 |
|
|
|
17,482,996 |
|
|
|
16,539,593 |
|
|
Adjustments to reconcile net income to net cash flows from
operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cumulative effect of accounting change
|
|
|
310,855 |
|
|
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
872,213 |
|
|
|
737,778 |
|
|
|
549,307 |
|
|
|
Accretion of asset retirement obligation
|
|
|
157,089 |
|
|
|
|
|
|
|
|
|
|
|
Loss on asset disposals
|
|
|
990 |
|
|
|
40,381 |
|
|
|
53,968 |
|
|
|
Changes in certain assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Trade accounts receivable
|
|
|
(640,329 |
) |
|
|
(185,960 |
) |
|
|
(1,665,075 |
) |
|
|
|
Inventories
|
|
|
(120,171 |
) |
|
|
261,259 |
|
|
|
(687,582 |
) |
|
|
|
Prepaid expenses
|
|
|
(63,094 |
) |
|
|
1,435 |
|
|
|
(23,012 |
) |
|
|
|
Other assets
|
|
|
|
|
|
|
(827 |
) |
|
|
59,379 |
|
|
|
|
Accounts payable
|
|
|
681,244 |
|
|
|
(950,936 |
) |
|
|
(616,539 |
) |
|
|
|
Accrued expenses
|
|
|
638,396 |
|
|
|
38,434 |
|
|
|
(93,095 |
) |
|
|
|
Other liabilities
|
|
|
(180,017 |
) |
|
|
(50,306 |
) |
|
|
1,068,796 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash flows from operating activities
|
|
|
17,610,891 |
|
|
|
17,374,254 |
|
|
|
15,185,740 |
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchases of property, plant, and equipment
|
|
|
(293,519 |
) |
|
|
(1,168,455 |
) |
|
|
(833,595 |
) |
|
Proceeds from sale of property, plant, and equipment
|
|
|
|
|
|
|
25,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash flows used in investing activities
|
|
|
(293,519 |
) |
|
|
(1,143,455 |
) |
|
|
(833,595 |
) |
|
|
|
|
|
|
|
|
|
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments on leases
|
|
|
(374,718 |
) |
|
|
(266,578 |
) |
|
|
(122,452 |
) |
|
Proceeds from (payments on) due to related parties
|
|
|
(10,000 |
) |
|
|
79,404 |
|
|
|
46,160 |
|
|
Distributions to stockholders
|
|
|
(16,863,787 |
) |
|
|
(11,607,377 |
) |
|
|
(8,578,953 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash flows used in financing activities
|
|
|
(17,248,505 |
) |
|
|
(11,794,551 |
) |
|
|
(8,655,245 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net change in cash and cash equivalents
|
|
|
68,867 |
|
|
|
4,436,248 |
|
|
|
5,696,900 |
|
Cash and cash equivalents beginning of year
|
|
|
16,890,439 |
|
|
|
12,454,191 |
|
|
|
6,757,291 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents end of year
|
|
$ |
16,959,306 |
|
|
|
16,890,439 |
|
|
|
12,454,191 |
|
|
|
|
|
|
|
|
|
|
|
Supplemental cash flow disclosures:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for interest
|
|
$ |
21,705 |
|
|
|
36,110 |
|
|
|
27,375 |
|
|
Noncash investing and financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reclamation liability for coal reserves
|
|
|
(2,474,301 |
) |
|
|
|
|
|
|
|
|
|
|
Acquisition of equipment through capital lease
|
|
|
|
|
|
|
302,374 |
|
|
|
522,086 |
|
See accompanying notes to combined financial statements.
F-95
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
December 31, 2002 and 2001
|
|
(1) |
Basis of Presentation and Organization |
The accompanying combined financial statements include certain
subsidiaries of Mears Enterprises, Inc. which operate six mining
complexes and a preparation plant all located in Pennsylvania
(The Combined Pennsylvania Entities of Mears Enterprises, Inc.,
or the Company). The Company is a producer and broker of
bituminous coal, with distribution and sales occurring primarily
in the northeastern part of the United States. Principal
customers of the Company are domestic public utilities,
industrial companies, and related parties.
Companies comprising The Combined Pennsylvania Entities of Mears
Enterprises, Inc., represented by function, are the following:
Coal sales and brokering:
|
|
|
|
|
Mears, Inc. (S-Corporation)
DLR Coal Company (General Partnership)
S&M Mining (General Partnership) |
Mine acquisition and development:
|
|
|
|
|
Mears, Inc. (S-Corporation)
DLR Mining, Inc. (C-Corporation)
S&M Mining, Inc. (S-Corporation) |
Functions performed within this group range from the very
initial stages of surveying land for mining potential,
performing surface mining and deep mining of all grades and
qualities of coal, transferring coal from the mine to storage
facilities, and the selling and brokering coal to both third and
related parties.
|
|
(2) |
Summary of Significant Accounting Policies and Practices |
|
|
|
(a) Basis of Presentation |
The combined financial statements include the accounts of The
Combined Pennsylvania Entities of Mears Enterprises, Inc. All
significant intercompany transactions and balances have been
eliminated.
|
|
|
(b) Cash and Cash Equivalents |
The Company defines cash and cash equivalents as highly liquid,
short-term investments with a maturity at the date of
acquisition of three months or less.
|
|
|
(c) Trade Accounts Receivable and Allowance for
Doubtful Accounts |
Trade accounts receivable are recorded at the invoiced amount
and do not bear interest. The allowance for doubtful accounts is
the Companys best estimate of the amount of probable
credit losses in the Companys existing accounts
receivable. The Company establishes provisions for losses on
accounts receivable when it is probable that all or part of the
outstanding balance will not be collected. The Company regularly
reviews collectibility and establishes or adjusts the allowance
as necessary using the specific identification method. The
allowance for doubtful accounts was $0 and $4,375 at
December 31, 2002 and 2001, respectively. Account balances
are charged off against the allowance after all means of
collection have been exhausted and the potential for recovery is
considered remote. The Company does not have any
off-balance-sheet credit exposure related to its customers.
F-96
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(Continued)
Coal inventory is stated at the lower of cost, with cost
determined using average monthly production costs, or market
value. Purchased coal is stated at purchase price. Coal
inventory at December 31, 2002 and 2001 was comprised of
raw and purchased coal.
|
|
|
(e) Shipping and Handling Costs |
Shipping and handling costs charged to customers have been
included in coal sales. Shipping and handling costs incurred by
the company have been included in cost of sales and other
operating expenses.
|
|
|
(f) Property, Plant, and Equipment |
Costs incurred as part of the acquisition of mineral interests
and mine development costs incurred to expand capacity of
operating mines or to develop new mines are capitalized and
charged to operations on the units-of-production method. Mine
development costs include costs incurred for site preparation
and development at the mines during the development stage.
Mobile mining equipment and other fixed assets are stated at
cost and depreciated on a straight-line basis over the estimated
useful lives ranging from 5 to 30 years or on a
units-of-production basis. Leasehold improvements are amortized,
using the straight-line method, over their estimated useful
lives or the term of the lease, whichever is shorter. Major
repairs and betterments that significantly extend original
useful lives or improve productivity are capitalized and
depreciated over the period benefited. Maintenance and repairs
are expensed as incurred.
|
|
|
(g) Asset Retirement Obligations |
Minimum standards for mine reclamation have been established by
various regulatory agencies and dictate the reclamation
requirements at the Companys operations.
In June 2001, the Financial Accounting Standards Board
(FASB) issued Statement of Financial Accounting Standards
(SFAS) No. 143, Accounting for Asset Retirement
Obligations. SFAS No. 143 requires the Company to
record the fair value of an asset retirement obligation as a
liability in the period in which it incurs a legal obligation
associated with the retirement of tangible long-lived assets
that result from the acquisition, construction, development,
and/or normal use of the assets. The Company also records a
corresponding asset that is depreciated over the life of the
asset. Subsequent to the initial measurement of the asset
retirement obligation, the obligation will be adjusted at the
end of each period to reflect the passage of time and changes in
the estimated future cash flows underlying the obligation.
The Company has future obligations to reclaim properties
disturbed in conjunction with coal operations under federal and
state laws. Some reclamation of disturbed acreage is performed
as a normal part of the mining process with the remainder done
at the end of the life of the mine. The Company adopted
SFAS No. 143, Accounting for Asset Retirement
Obligations, on January 1, 2003. Upon adoption,
property, plant, and equipment (net) were increased by
$2,163,446; asset retirement obligations were increased by
$2,474,301; and the cumulative effect of the accounting change
was $(310,855).
Prior to January 1, 2003, the estimated cost for mine
reclamation was provided for using the units of production
method over the economic life of the mine. Estimated reclamation
costs were subject to review by management on a regular basis
and revised when appropriate for changes in future estimated
costs and/or regulatory requirements.
F-97
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(Continued)
|
|
|
(h) Advance Mining Royalties |
Rights to leased coal lands are often acquired in exchange for
royalty payments. Advance mining royalties are advance payments
made to lessors under terms of mineral lease agreements that are
recoupable against future production. These advance payments are
deferred and charged to operations as the coal reserves are
mined. In instances where advance payments are not expected to
be offset against future production royalties, no asset is
recognized and the scheduled future minimum payments are
recognized as liabilities.
Revenue is recognized on coal sales at the time of shipment or
delivery to the customer, and the customer takes ownership and
assumes risk of loss based on shipping terms.
|
|
|
(j) Impairment of Long-Lived Assets |
In accordance with SFAS No. 144, Accounting for the
Impairment or Disposal of Long-lived Assets, long-lived
assets, such as property, plant, equipment, and purchased
intangibles subject to amortization, are reviewed for impairment
whenever events or changes in circumstances indicate that the
carrying amount of an asset may not be recoverable.
Recoverability of assets to be held and used is measured by a
comparison of the carrying amount of an asset to estimated
undiscounted future cash flows expected to be generated by the
asset. If the carrying amount of an asset exceeds its estimated
future cash flows, an impairment charge is recognized by the
amount by which the carrying amount of the asset exceeds the
fair value of the asset. Assets to be disposed of would be
separately presented in the balance sheet and reported at the
lower of the carrying amount or fair value less costs to sell
and would no longer be depreciated. The assets and liabilities
of a disposal group classified as held for sale would be
presented separately in the appropriate asset and liability
sections of the balance sheet.
All companies included in The Combined Pennsylvania Entities of
Mears Enterprises, Inc. are either S corporations or
general partnerships except for DLR Mining, Inc. Under each of
these structures, for income tax purposes the net income or loss
of the S corporation and general partnership is allocated
directly to the respective shareholders and or partners and is
included in their individual tax returns. Therefore, no
provision for income tax has been included in the combined
financial statements for these entities. DLR Mining, Inc. has a
net deferred tax asset for which a valuation allowance has been
provided. The significant components of the net deferred tax
asset are net operating loss carryforwards and certain
liabilities which have not yet been deducted for tax purposes.
|
|
|
(l) Risks and Uncertainties |
The Company is engaged in the production of steam and
metallurgical coal for the electric generating industry as well
as industrial customers. Coal produced from the Companys
reserves located in Pennsylvania is sold to energy companies
throughout the northeastern part of the United States primarily
under long-term supply agreements. Additional production from
Company reserves not covered under supply contracts is sold on
the open market. The Company is subject to risks and
uncertainties related to the creditworthiness of customers in
the energy industry as well as price, supply, demand, and other
volatility associated with coal commodity markets. Commodities
markets and economic conditions have been volatile in the past
and can be expected to be volatile in the future.
F-98
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(Continued)
The Company had three customers that accounted for approximately
46%, 18%, and 15% of the Companys net sales and two
customers that accounted for approximately 61% and 17% of the
Companys trade accounts receivable as of and for the year
ended December 31, 2002. The Company had one customer that
accounted for approximately 35% of the Companys net sales
and 35% of the Companys trade accounts receivable as of
and for the year ended December 31, 2001.
(m) Workers
Compensation and Pneumoconiosis (Black Lung) Benefits
The Company is insured for workers compensation claims.
The Company is required by federal and state statutes to provide
benefits to employees for awards related to black lung. The
Company is fully insured for this obligation.
The preparation of the consolidated financial statements in
conformity with accounting principles generally accepted in the
United States of America requires management to make estimates
and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities
at the date of the consolidated financial statements and the
reported amounts of revenues and expenses during the reporting
period. The more significant items requiring the use of
management estimates are allowances for doubtful accounts;
mineral reserves; reclamation and mine closure obligations;
employee benefit liabilities; future cash flows associated with
assets; and useful lives for depreciation, depletion, and
amortization. Due to the prospective nature of these estimates,
actual results could differ from those estimates.
Prepaid expenses consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2002 | |
|
2001 | |
|
|
| |
|
| |
Prepaid capital stock tax
|
|
$ |
10,955 |
|
|
$ |
5,288 |
|
Prepaid royalties
|
|
|
17,863 |
|
|
|
24,965 |
|
Prepaid other
|
|
|
10,995 |
|
|
|
10,995 |
|
|
|
|
|
|
|
|
|
Total prepaid expenses
|
|
$ |
39,813 |
|
|
$ |
41,248 |
|
|
|
|
|
|
|
|
|
|
(4) |
Property, Plant, and Equipment |
Property, plant, and equipment consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2002 | |
|
2001 | |
|
|
| |
|
| |
Land
|
|
$ |
655,015 |
|
|
$ |
655,015 |
|
Mineral interests and mine development costs
|
|
|
1,723,664 |
|
|
|
1,723,664 |
|
Buildings and improvements
|
|
|
148,011 |
|
|
|
94,196 |
|
Machinery and equipment
|
|
|
5,747,978 |
|
|
|
4,406,777 |
|
|
|
|
|
|
|
|
|
|
|
8,274,668 |
|
|
|
6,879,652 |
|
Less accumulated depreciation, depletion, and amortization
|
|
|
(2,731,325 |
) |
|
|
(2,003,979 |
) |
|
|
|
|
|
|
|
|
Total property, plant, and equipment
|
|
$ |
5,543,343 |
|
|
$ |
4,875,673 |
|
|
|
|
|
|
|
|
F-99
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(Continued)
Accrued expenses consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2002 | |
|
2001 | |
|
|
| |
|
| |
Wages
|
|
$ |
492,407 |
|
|
$ |
378,013 |
|
Workers compensation
|
|
|
86,803 |
|
|
|
95,019 |
|
Retirement 401(k) Plan
|
|
|
68,632 |
|
|
|
128,141 |
|
Office of Surface Mining and excise tax
|
|
|
118,395 |
|
|
|
121,101 |
|
Other liabilities
|
|
|
26,671 |
|
|
|
32,200 |
|
|
|
|
|
|
|
|
|
|
$ |
792,908 |
|
|
$ |
754,474 |
|
|
|
|
|
|
|
|
|
|
(6) |
Capital Lease Obligations |
The Company leases certain equipment under capital lease
agreements. These agreements have varying monthly payment
amounts and expire on various dates during 2003. Amortization
expense on the capitalized cost of leased property for the
period from January 1, 2003 through November 17, 2003
was $21,705.
The capitalized cost of the leased property and accumulated
depreciation at December 31, 2002 was $691,411 and $91,717.
Amortization expense on the capitalized cost of leased property
for the year ended December 31, 2002 was $19,894.
The capitalized cost of the leased property and accumulated
depreciation at December 31, 2001 was $534,036 and $31,383.
Amortization expense on the capitalized cost of leased property
for the year ended December 31, 2001 was $10,071.
The following is a schedule of future minimum lease payments
under capital lease together with the present value of the net
minimum lease payments as of December 31, 2002 and 2001:
|
|
|
|
|
|
|
|
|
|
|
|
|
2002 | |
|
2001 | |
|
|
| |
|
| |
Future minimum lease payments due in:
|
|
|
|
|
|
|
|
|
|
2002
|
|
$ |
|
|
|
|
253,308 |
|
|
2003
|
|
|
400,946 |
|
|
|
170,337 |
|
|
2004
|
|
|
63,982 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total future minimum lease payments
|
|
|
464,928 |
|
|
|
423,645 |
|
|
Less amount representing interest
|
|
|
(29,498 |
) |
|
|
(24,011 |
) |
|
|
|
|
|
|
|
|
|
Present value of future minimum lease payments
|
|
|
435,430 |
|
|
|
399,634 |
|
|
Less current portion
|
|
|
(374,718 |
) |
|
|
(234,497 |
) |
|
|
|
|
|
|
|
|
|
Long-term capital lease obligation
|
|
$ |
60,712 |
|
|
|
165,137 |
|
|
|
|
|
|
|
|
|
|
(7) |
Reclamation Liabilities |
Under the Federal Surface Mining Control and Reclamation Act of
1977 and similar state statutes, mine property is required to be
restored in accordance with regulated standards. The
establishment of the asset retirement obligation accrual for
mine reclamation and mine closure costs is based on permit
requirements and requires various estimates and assumptions,
principally associated with costs, productivi-
F-100
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(Continued)
ties, and timing of expenditures. The Company periodically
reviews its entire environmental liability and makes necessary
adjustments, including permit changes, revisions to costs and
productivities to reflect current experience, and accretion
related to the liability. At November 17, 2003, the asset
retirement obligation was estimated to be $3,649,880. The
activity in the asset retirement obligation consisted of the
following during the period from January 1, 2003 through
November 17, 2003:
|
|
|
|
|
Asset retirement obligation January 1, 2003
|
|
$ |
3,492,791 |
|
Obligations settled in current period
|
|
|
|
|
Accretion expense January 1, 2003
November 17, 2003
|
|
|
157,089 |
|
|
|
|
|
Asset retirement obligation November 17, 2003
|
|
$ |
3,649,880 |
|
|
|
|
|
|
|
(8) |
Workers Compensation Benefits |
The Company is insured for workers compensation claims.
The liability for workers compensation claims is a
management estimate of the ultimate losses to be incurred on
such claims based on the Companys experience and includes
a provision for incurred but not reported losses. Adjustments to
the probable ultimate liability are made annually based on
subsequent developments and experience and are included in
operations as they are determined. These obligations are
currently insured by Rockwood Casualty Insurance, an unrelated
entity.
The liability for workers compensation benefits at
December 31, 2002 and 2001 was $86,803 and $95,019,
respectively, which is included in accrued expenses.
Workers compensation expenses for the period from
January 1, 2003 to November 17, 2003 and for the years
ended December 31, 2002 and 2001 were $1,550,447, $886,326,
and $735,513, respectively.
Mears Enterprises, Inc. & Affiliates maintains a 401(k)
for substantially all full-time employees. Company contributions
to the 401(k) plan, which are made at the discretion of
management, for the period from January 1, 2003 to
November 17, 2003 and for the years ended December 31,
2002 and 2001 were $166,253, $235,310, and $368,097,
respectively.
|
|
(10) |
Leased Mineral Interests |
In addition to mining coal on Company owned land, the Company
also mines coal on properties leased from independent third
parties. Under the terms of the leases, the Company pays minimum
royalty payments. The Company also pays production royalties
based on a percentage of the net sales price of coal produced or
based on the actual tonnage mined from the leased premises.
These royalty payments range from $0.07 per ton mined to
10% of sales.
F-101
THE COMBINED PENNSYLVANIA ENTITIES OF
MEARS ENTERPRISES, INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(Continued)
As of December 31, 2002, aggregate future minimum royalty
payments under these leases were as follows:
|
|
|
|
|
|
|
|
Amount | |
|
|
| |
2003
|
|
$ |
17,581 |
|
2004
|
|
|
68,581 |
|
2005
|
|
|
68,581 |
|
2006
|
|
|
68,581 |
|
2007
|
|
|
68,581 |
|
Thereafter
|
|
|
137,162 |
|
|
|
|
|
|
Total estimated future payments
|
|
$ |
429,067 |
|
|
|
|
|
Other income consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Period from | |
|
|
|
|
|
|
January 1 to | |
|
Year Ended | |
|
Year Ended | |
|
|
November 17, | |
|
December 31, | |
|
December 31, | |
|
|
2003 | |
|
2002 | |
|
2001 | |
|
|
| |
|
| |
|
| |
Subcontractor income
|
|
$ |
447,040 |
|
|
|
122,452 |
|
|
|
611,133 |
|
Sales commission
|
|
|
|
|
|
|
|
|
|
|
460,870 |
|
Loss on disposal of property, plant, and equipment
|
|
|
(990 |
) |
|
|
(40,381 |
) |
|
|
(53,968 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
$ |
446,050 |
|
|
|
82,071 |
|
|
|
1,018,035 |
|
|
|
|
|
|
|
|
|
|
|
On November 17, 2003, the assets of The Combined
Pennsylvania Entities of Mears Enterprises, Inc. were sold to
AMFIRE Mining Company, LLC, a wholly owned subsidiary of Alpha
Natural Resources, LLC.
F-102
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Condensed Combined Balance Sheets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
(Unaudited) | |
|
|
ASSETS |
Current assets:
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
22,997,865 |
|
|
|
12,707,479 |
|
|
Trade accounts receivable
|
|
|
13,570,225 |
|
|
|
9,555,345 |
|
|
Notes and other receivables
|
|
|
422,879 |
|
|
|
3,472,105 |
|
|
Inventories
|
|
|
8,161,752 |
|
|
|
6,914,783 |
|
|
Due from affiliate
|
|
|
76,502 |
|
|
|
87,674 |
|
|
Prepaid expenses and other current assets
|
|
|
2,668,872 |
|
|
|
1,791,141 |
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
47,898,095 |
|
|
|
34,528,527 |
|
Property, plant, and equipment, net
|
|
|
80,127,635 |
|
|
|
68,116,844 |
|
Other assets
|
|
|
2,770,742 |
|
|
|
2,911,155 |
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
130,796,472 |
|
|
|
105,556,526 |
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY AND MEMBERS
EQUITY |
Current liabilities:
|
|
|
|
|
|
|
|
|
|
Current portion of long-term debt
|
|
$ |
14,282,214 |
|
|
|
11,467,093 |
|
|
Note payable stockholder
|
|
|
1,690,605 |
|
|
|
2,093,630 |
|
|
Note payable affiliate
|
|
|
|
|
|
|
400,000 |
|
|
Trade accounts payable
|
|
|
8,099,388 |
|
|
|
5,480,123 |
|
|
Accrued expenses and other current liabilities
|
|
|
7,657,188 |
|
|
|
7,105,947 |
|
|
Due to affiliate
|
|
|
|
|
|
|
26,157 |
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
31,729,395 |
|
|
|
26,572,950 |
|
Long-term debt, net of current portion
|
|
|
27,896,947 |
|
|
|
20,767,857 |
|
Asset retirement obligation
|
|
|
8,721,200 |
|
|
|
8,922,800 |
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
68,347,542 |
|
|
|
56,263,607 |
|
|
|
|
|
|
|
|
Stockholders equity and members equity:
|
|
|
|
|
|
|
|
|
|
Stockholders equity:
|
|
|
|
|
|
|
|
|
|
|
Common stock, $10 par value. Authorized, issued and
outstanding 25,300 shares
|
|
|
253,000 |
|
|
|
253,000 |
|
|
|
Additional paid-in capital
|
|
|
12,248,436 |
|
|
|
12,248,436 |
|
|
|
Retained earnings (accumulated deficit)
|
|
|
33,100,645 |
|
|
|
(6,376,611 |
) |
|
|
Accumulated other comprehensive income
|
|
|
43,024 |
|
|
|
57,641 |
|
|
|
Notes payable stockholders distributions
|
|
|
14,977,000 |
|
|
|
41,313,293 |
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
60,622,105 |
|
|
|
47,495,759 |
|
|
Members equity
|
|
|
1,826,825 |
|
|
|
1,797,160 |
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity and members equity
|
|
|
62,448,930 |
|
|
|
49,292,919 |
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity and
members equity
|
|
$ |
130,796,472 |
|
|
|
105,556,526 |
|
|
|
|
|
|
|
|
See accompanying notes to condensed combined financial
statements.
F-103
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Condensed Combined Statements of Income
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
September 30, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
(Unaudited) | |
Revenues:
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
141,371,248 |
|
|
|
101,663,228 |
|
|
Other revenues
|
|
|
15,483,721 |
|
|
|
4,533,220 |
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
156,854,969 |
|
|
|
106,196,448 |
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
Cost of coal revenues (exclusive of items shown separately below)
|
|
|
88,008,415 |
|
|
|
72,396,661 |
|
|
Cost of other revenues
|
|
|
13,764,787 |
|
|
|
3,203,735 |
|
|
Depreciation, depletion and amortization
|
|
|
10,339,708 |
|
|
|
8,507,516 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
2,668,187 |
|
|
|
2,403,321 |
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
114,781,097 |
|
|
|
86,511,233 |
|
|
|
|
|
|
|
|
Loss on sale of fixed assets, net
|
|
|
(559,852 |
) |
|
|
(4,974 |
) |
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
41,514,020 |
|
|
|
19,680,241 |
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,592,650 |
) |
|
|
(964,135 |
) |
|
Interest income
|
|
|
301,984 |
|
|
|
66,386 |
|
|
Equity in loss of affiliate
|
|
|
(85,731 |
) |
|
|
(114,897 |
) |
|
Miscellaneous income, net
|
|
|
177,298 |
|
|
|
72,776 |
|
|
|
|
|
|
|
|
|
|
Total other expense, net
|
|
|
(1,199,099 |
) |
|
|
(939,870 |
) |
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
40,314,921 |
|
|
|
18,740,371 |
|
|
|
|
|
|
|
|
See accompanying notes to condensed combined financial
statements.
F-104
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Condensed Combined Statements of Stockholders Equity
and Members Equity and
Comprehensive Income
Nine months ended September 30, 2005 and year ended
December 31, 2004
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders Equity | |
|
|
|
|
|
|
| |
|
|
|
Total | |
|
|
|
|
Retained | |
|
Accumulated | |
|
Notes | |
|
|
|
|
|
Stockholders | |
|
|
|
|
Additional | |
|
Earnings | |
|
Other | |
|
Payable | |
|
Total | |
|
|
|
Equity and | |
|
|
Common | |
|
Paid-In | |
|
(Accumulated | |
|
Comprehensive | |
|
Stockholders | |
|
Stockholders | |
|
Members | |
|
Members | |
|
|
Stock | |
|
Capital | |
|
Deficit) | |
|
Income | |
|
Distributions | |
|
Equity | |
|
Equity | |
|
Equity | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Balances, December 31, 2003
|
|
$ |
253,000 |
|
|
|
12,248,436 |
|
|
|
(15,187,848 |
) |
|
|
36,434 |
|
|
|
32,685,477 |
|
|
|
30,035,499 |
|
|
|
1,743,774 |
|
|
|
31,779,273 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
23,611,237 |
|
|
|
|
|
|
|
|
|
|
|
23,611,237 |
|
|
|
1,266,354 |
|
|
|
24,877,591 |
|
|
Change in unrealized gains on securities available for sale
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
21,207 |
|
|
|
|
|
|
|
21,207 |
|
|
|
|
|
|
|
21,207 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
24,898,798 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note repayments
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(6,172,184 |
) |
|
|
(6,172,184 |
) |
|
|
|
|
|
|
(6,172,184 |
) |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
(14,800,000 |
) |
|
|
|
|
|
|
14,800,000 |
|
|
|
|
|
|
|
(1,212,968 |
) |
|
|
(1,212,968 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2004
|
|
|
253,000 |
|
|
|
12,248,436 |
|
|
|
(6,376,611 |
) |
|
|
57,641 |
|
|
|
41,313,293 |
|
|
|
47,495,759 |
|
|
|
1,797,160 |
|
|
|
49,292,919 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
39,477,256 |
|
|
|
|
|
|
|
|
|
|
|
39,477,256 |
|
|
|
837,665 |
|
|
|
40,314,921 |
|
|
Change in unrealized gains on securities available for sale
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(14,617 |
) |
|
|
|
|
|
|
(14,617 |
) |
|
|
|
|
|
|
(14,617 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
40,300,304 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note repayments
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(26,336,293 |
) |
|
|
(26,336,293 |
) |
|
|
|
|
|
|
(26,336,293 |
) |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(808,000 |
) |
|
|
(808,000 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, September 30, 2005
|
|
$ |
253,000 |
|
|
|
12,248,436 |
|
|
|
33,100,645 |
|
|
|
43,024 |
|
|
|
14,977,000 |
|
|
|
60,622,105 |
|
|
|
1,826,825 |
|
|
|
62,448,930 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to condensed combined financial
statements.
F-105
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Condensed Combined Statements of Cash Flows
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
September 30, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
(Unaudited) | |
Operating activities:
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
40,314,921 |
|
|
|
18,740,371 |
|
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
10,339,708 |
|
|
|
8,507,516 |
|
|
|
Equity in loss of affiliate
|
|
|
85,731 |
|
|
|
114,897 |
|
|
|
Accretion of asset retirement obligation
|
|
|
386,400 |
|
|
|
307,200 |
|
|
|
Loss on sale of fixed assets, net
|
|
|
559,852 |
|
|
|
4,974 |
|
|
|
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
Trade accounts receivable
|
|
|
(4,014,880 |
) |
|
|
(2,094,215 |
) |
|
|
|
Notes and other receivables
|
|
|
3,049,226 |
|
|
|
3,655,520 |
|
|
|
|
Inventories
|
|
|
(1,246,969 |
) |
|
|
(2,344,226 |
) |
|
|
|
Due from affiliate
|
|
|
11,172 |
|
|
|
14,146 |
|
|
|
|
Prepaid expenses and other current assets
|
|
|
(641,565 |
) |
|
|
(646,243 |
) |
|
|
|
Other assets
|
|
|
119,682 |
|
|
|
(34,432 |
) |
|
|
|
Trade accounts payable
|
|
|
2,619,265 |
|
|
|
1,113,765 |
|
|
|
|
Accrued expenses and other current liabilities
|
|
|
(287,542 |
) |
|
|
649,159 |
|
|
|
|
Due to affiliate
|
|
|
(26,157 |
) |
|
|
83,487 |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
51,268,844 |
|
|
|
28,071,919 |
|
|
|
|
|
|
|
|
Investing activities:
|
|
|
|
|
|
|
|
|
|
Capital expenditures, including interest capitalized
|
|
|
(3,101,058 |
) |
|
|
(845,151 |
) |
|
Proceeds from disposition of property, plant, and equipment
|
|
|
530,000 |
|
|
|
23,200 |
|
|
Investment in affiliate
|
|
|
(65,000 |
) |
|
|
(100,000 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(2,636,058 |
) |
|
|
(921,951 |
) |
|
|
|
|
|
|
|
Financing activities:
|
|
|
|
|
|
|
|
|
|
Repayments on long-term debt
|
|
|
(10,395,082 |
) |
|
|
|
|
|
Repayment on note payable affiliate
|
|
|
(400,000 |
) |
|
|
(8,809,402 |
) |
|
Repayments on notes payable stockholder
|
|
|
(403,025 |
) |
|
|
(3,517,543 |
) |
|
Repayments on notes payable stockholders
distributions
|
|
|
(26,336,293 |
) |
|
|
(5,172,184 |
) |
|
Distributions to owners
|
|
|
(808,000 |
) |
|
|
(952,827 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities
|
|
|
(38,342,400 |
) |
|
|
(18,451,956 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net increase in cash and cash equivalents
|
|
|
10,290,386 |
|
|
|
8,698,012 |
|
Cash and cash equivalents at beginning of period
|
|
|
12,707,479 |
|
|
|
1,786,881 |
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$ |
22,997,865 |
|
|
|
10,484,893 |
|
|
|
|
|
|
|
|
See accompanying notes to condensed combined financial
statements.
F-106
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004
(Unaudited)
|
|
(1) |
Business and Basis of Presentation |
|
|
(a) |
Organization and Business |
The accompanying unaudited condensed combined financial
statements include the accounts of the coal mining operations of
The Combined Entities of The Nicewonder Coal Group
(collectively, the Company). All affiliated companies within the
group are under common management and control.
The Company is primarily engaged in the business of extracting,
processing and marketing coal from surface mines, principally
located in West Virginia and Virginia, for sale to electric
utilities and steel producers in the United States. The Company
is also engaged in the road construction contracting business in
cooperation with the West Virginia Department of Transportation
Division of Highways that permits the Company to recover the
coal removed in the construction process.
Companies comprising the coal mining operations of the Company
are the following:
|
|
|
Mate Creek Energy of W. Va., Inc. (Mate Creek) (S-Corporation) |
|
Buchanan Energy Company, LLC (Buchanan Energy) (Limited
Liability Company) |
|
Virginia Energy Company (Virginia Energy) (S-Corporation) |
|
Nicewonder Contracting, Inc. (Nicewonder Contracting)
(S-Corporation) |
|
White Flame Energy, Inc. (White Flame Energy) (S-Corporation) |
|
Premium Energy, Inc. (Premium Energy) (S-Corporation) |
|
Twin Star Mining, Inc. (Twin Star) (S-Corporation) |
|
Powers Shop, LLC (Powers Shop) (Limited Liability Company) |
Functions performed within this group range from the very
initial stages of surveying land for mining potential,
performing surface mining of all grades and qualities of coal,
transferring coal from the mine to storage facilities, and the
selling of coal to both third and related parties.
|
|
(b) |
Principles of Combination |
The accompanying unaudited condensed combined financial
statements include the accounts of the companies described
above. All significant intercompany accounts and transactions
have been eliminated in combination.
|
|
(c) |
Basis of Presentation |
The accompanying unaudited condensed combined financial
statements have been prepared in accordance with
U.S. generally accepted accounting principles for interim
financial reporting. Accounting measurements at interim dates
inherently rely on estimates more than year end; however, in the
opinion of management, all adjustments consisting of normal
recurring accruals) considered necessary for a fair presentation
have been included. Results of operations for the nine months
ended September 30, 2005 are not necessarily indicative of
the results to be expected for the year ending December 31,
2005. These financial statements should be read in conjunction
with the audited combined financial statements and related notes
as of and for the year ended December 31, 2004.
F-107
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004 (Continued)
(Unaudited)
|
|
(2) |
Trade Accounts Receivable |
Trade accounts receivable consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Accounts receivable, unrelated parties
|
|
$ |
4,791,325 |
|
|
$ |
2,332,587 |
|
Accounts receivable, affiliated agent
|
|
|
5,220,139 |
|
|
|
1,806,692 |
|
Road construction contracts receivable:
|
|
|
|
|
|
|
|
|
|
Billed
|
|
|
1,352,833 |
|
|
|
3,281,924 |
|
|
Unbilled
|
|
|
2,205,928 |
|
|
|
2,134,142 |
|
|
|
|
|
|
|
|
|
|
Total trade accounts receivable
|
|
$ |
13,570,225 |
|
|
$ |
9,555,345 |
|
|
|
|
|
|
|
|
Inventories consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Raw coal
|
|
$ |
493,936 |
|
|
$ |
291,549 |
|
Saleable coal
|
|
|
2,833,716 |
|
|
|
2,387,608 |
|
Materials and supplies
|
|
|
4,834,100 |
|
|
|
4,235,626 |
|
|
|
|
|
|
|
|
|
Total inventories
|
|
$ |
8,161,752 |
|
|
$ |
6,914,783 |
|
|
|
|
|
|
|
|
|
|
(4) |
Property, Plant, and Equipment |
Property, plant, and equipment consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Land
|
|
$ |
1,842,219 |
|
|
$ |
1,462,712 |
|
Mineral rights
|
|
|
6,846,807 |
|
|
|
6,673,230 |
|
Plant and mining equipment
|
|
|
152,735,910 |
|
|
|
145,668,580 |
|
Vehicles
|
|
|
2,659,533 |
|
|
|
2,491,369 |
|
Mine development
|
|
|
8,082,991 |
|
|
|
6,892,172 |
|
Office equipment and software
|
|
|
130,632 |
|
|
|
130,632 |
|
|
|
|
|
|
|
|
|
|
|
172,298,092 |
|
|
|
163,318,695 |
|
Accumulated depreciation, depletion and amortization
|
|
|
(92,170,457 |
) |
|
|
(95,201,851 |
) |
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
$ |
80,127,635 |
|
|
$ |
68,116,844 |
|
|
|
|
|
|
|
|
F-108
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004 (Continued)
(Unaudited)
Information with respect to the uncompleted road construction
contract as of September 30, 2005 is summarized as follows:
|
|
|
|
|
Costs incurred on uncompleted contract
|
|
$ |
22,867,601 |
|
Estimated earnings thereon
|
|
|
|
|
|
|
|
|
|
|
|
22,867,601 |
|
Less billings to date
|
|
|
21,747,833 |
|
|
|
|
|
|
|
$ |
1,119,768 |
|
|
|
|
|
Costs and estimated earnings in excess of billings on
uncompleted contract
|
|
$ |
1,119,768 |
|
Billings in excess of costs and estimated earnings on
uncompleted contract
|
|
|
|
|
|
|
|
|
|
|
$ |
1,119,768 |
|
|
|
|
|
In May 2004, Nicewonder Contracting entered into a contract
agreement with the West Virginia Department of Transportation
Division of Highways (WVDOH) for the construction of a road
project by performing excavation services and providing subgrade
materials to assist in the construction of the road. The road
project is titled the Red Jacket Project and is part
of the King Coal Highway project in West Virginia. As part of
the agreement, Nicewonder Contracting is assisting the WVDOH by
assuming the lead role in obtaining from large tract owners
sufficient legal rights to the rights-of-ways necessary to
construct the Red Jacket Project and assisting in getting the
surface lands and rights-of-ways conveyed to WVDOH. The project
is expected to take approximately six years to complete. The Red
Jacket Project is Nicewonder Contractings only project in
progress as of September 30, 2005.
Based on the terms of the contract with WVDOH, Nicewonder
Contracting is reimbursed based on units of in-place cubic yards
excavated and associated unit costs. The road construction
project is expected to be a zero profit contract over the life
of the project. As part of the contract agreement, Nicewonder
Contracting is allowed to remove and sell any and all coal
excavated during the construction process with all coal sales
revenue recognized by Nicewonder Contracting.
The Company had uncompleted and scheduled road construction
contracts at September 30, 2005 as follows:
|
|
|
|
|
|
|
|
Contracts in progress:
|
|
|
|
|
|
Gross contracts awarded
|
|
$ |
94,397,767 |
|
|
|
Less completed portions
|
|
|
22,867,601 |
|
|
|
|
|
|
|
|
71,530,166 |
|
Scheduled contracts
|
|
|
8,482,625 |
|
|
|
|
|
|
|
|
Totals
|
|
$ |
80,012,791 |
|
|
|
|
|
F-109
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004 (Continued)
(Unaudited)
Long-term debt consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
September 30, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Fixed rate term notes
|
|
$ |
40,535,934 |
|
|
|
29,640,285 |
|
Variable rate term notes
|
|
|
1,643,227 |
|
|
|
2,594,665 |
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
|
42,179,161 |
|
|
|
32,234,950 |
|
Less current portion of long-term debt
|
|
|
14,282,214 |
|
|
|
11,467,093 |
|
|
|
|
|
|
|
|
|
Long-term debt, net of current portion
|
|
$ |
27,896,947 |
|
|
|
20,767,857 |
|
|
|
|
|
|
|
|
|
|
(7) |
Asset Retirement Obligation |
Under the Federal Surface Mining Control and Reclamation Act of
1977 and similar state statutes, mine property is required to be
restored in accordance with regulated standards. The
establishment of the asset retirement obligation accrual for
mine reclamation and mine closure costs is based on permit
requirements and requires various estimates and assumptions,
principally associated with costs, productivities, and timing of
expenditures. The Company periodically reviews its entire
environmental liability and makes necessary adjustments,
including permit changes, revisions to costs and productivities
to reflect current experience, and accretion related to the
liability.
At September 30, 2005 and December 31, 2004, the
Company has recorded asset retirement obligation accruals for
mine reclamation and closure costs totaling $9,309,200 and
$8,922,800, respectively. The portion of the costs expected to
be incurred within one year in the amount of $588,000 at
September 30, 2005 is included in accrued expenses and
other current liabilities. Changes in the asset retirement
obligation were as follows:
|
|
|
|
|
|
Total asset retirement obligation at December 31, 2004
|
|
$ |
8,922,800 |
|
Accretion for nine months ended September 30, 2005
|
|
|
386,400 |
|
|
|
|
|
|
Total asset retirement obligation at September 30, 2005
|
|
$ |
9,309,200 |
|
|
|
|
|
|
|
(8) |
Notes Payable Stockholders
Distributions |
Notes payable stockholders distributions
consisted of notes payable issued to the stockholders of the
Company in lieu of cash distributions. The notes are noninterest
bearing and are due on demand. However, each December 31,
the stockholders waive their rights to call the amounts due for
a period of 18 months. The outstanding balance of the notes
payable stockholders distributions at
September 30, 2005 and December 31, 2004 was
$14,977,000 and $41,313,293, respectively. Given the nature of
these notes payable to stockholders, the notes have been
reflected as part of total stockholders equity and
members equity in the accompanying condensed combined
financial statements.
F-110
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004 (Continued)
(Unaudited)
|
|
(9) |
Related Party Transactions |
The Companys stockholders consist of individuals that are
also owners in other entities that transact business with the
Company. Amounts included in the accompanying condensed combined
statements of income with respect to transactions with related
parties are as follows:
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
September 30, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Management and engineering fees
|
|
$ |
281,116 |
|
|
|
257,533 |
|
Interest income
|
|
|
53,197 |
|
|
|
45,760 |
|
Interest expense
|
|
|
2,110 |
|
|
|
21,770 |
|
Rental income
|
|
|
78,475 |
|
|
|
64,315 |
|
A large portion of the Companys coal sales and shipments
are made through an affiliated company as agent. In conjunction
with these sales, the affiliated company collects amounts due
from customers and advances funds to the Company in anticipation
of their collection and receives a commission for such services.
Commission expense incurred by the Company pursuant to this
arrangement was $627,446 and $606,076 for the nine months ended
September 30, 2005 and 2004, respectively.
The Company is involved in various legal proceedings from time
to time in the normal course of business. In managements
opinion, the Company is not currently involved in any legal
proceeding which individually or in the aggregate could have a
material effect on the combined financial condition, results of
operations and/or cash flows of the Company.
|
|
(11) |
Supplemental Cash Flow Disclosures |
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended | |
|
|
September 30, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Cash paid for interest (net of amounts capitalized)
|
|
$ |
1,541,334 |
|
|
|
982,202 |
|
Noncash investing and financing activities:
|
|
|
|
|
|
|
|
|
|
Property and equipment purchases financed with notes payable to
sellers
|
|
|
20,339,293 |
|
|
|
21,175,375 |
|
|
Addition to asset retirement obligation asset and liability
|
|
|
|
|
|
|
1,906,000 |
|
|
|
(12) |
New Accounting Pronouncements |
In November 2004, the Financial Accounting Standards Board
(FASB) issued Statement of Financial Accounting Standards
(SFAS) No. 151, Inventory Costs which amends
the guidance in ARB No. 43, Chapter 4 Inventory
Pricing, to clarify the accounting for abnormal amounts of
idle facility expense, freight, handling costs, and wasted
material (spoilage). Paragraph 5 of ARB 43, Chapter 4,
previously stated that under some circumstances, items such as
idle facility expense, excessive spoilage, double freight, and
rehandling costs may be so abnormal as to require treatment as
current period charges. SFAS No. 151 requires that
those items be recognized as current-period charges regardless
of whether they meet the criterion of so abnormal.
In addition, SFAS No. 151 requires that allocation of
fixed production overheads to the costs of conversion be based
on the normal capacity of the production
F-111
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004 (Continued)
(Unaudited)
facilities. SFAS No. 151 shall be effective for
inventory costs incurred during fiscal years beginning after
September 15, 2005. Earlier application is permitted for
inventory costs incurred during fiscal years beginning after the
date SFAS No. 151 was issued. SFAS No. 151
shall be applied prospectively. The Company does not expect the
adoption of SFAS No. 151 to have a material effect on
its combined financial statements.
In December 2004, the FASB issued SFAS No. 153,
Exchanges of Nonmonetary Assets, which amends Accounting
Principles Board (APB) Opinion No. 29, Accounting
for Nonmonetary Transactions. APB Opinion No. 29 is
based on the principle that exchanges of nonmonetary assets
should be measured based on the fair value of the assets
exchanged. The guidance in that Opinion, however, included
certain exceptions to that principle. SFAS No. 153
amends APB Opinion No. 29 to eliminate the exception for
nonmonetary exchanges of similar productive assets and replaces
it with a general exception for exchanges of nonmonetary assets
that do not have commercial substance. A nonmonetary exchange
has commercial substance if the future cash flows of the entity
are expected to change significantly as a result of the
exchange. SFAS No. 153 shall be effective for
nonmonetary asset exchanges occurring in fiscal periods
beginning after September 15, 2005. Earlier application is
permitted for nonmonetary asset exchanges occurring in fiscal
periods beginning after the date SFAS No. 153 was
issued. SFAS No. 153 shall be applied prospectively.
The Company does not expect the adoption of
SFAS No. 153 to have a material effect on its combined
financial statements.
On March 17, 2005, the Emerging Issues Task Force
(EITF) of the FASB reached consensus on EITF Issue
No. 04-6, Accounting for Stripping Costs Incurred during
Production in the Mining Industry, and on March 30,
2005, the FASB Board ratified the consensus. The EITF reached
consensus that stripping costs incurred during the production
phase of a mine are variable production costs that should be
included in the costs of inventory produced during the period
that the stripping costs are incurred. ETIF 04-6 is effective
for the first reporting period in fiscal years beginning after
December 15, 2005 with early adoption permitted. The
Company does not expect that the adoption of EITF 04-6 will
have any material financial statement impact.
In March 2005, the FASB issued Interpretation No. 47,
Accounting for Conditional Asset Retirement Obligations,
an interpretation of SFAS No. 143, Accounting for
Asset Retirement Obligations. This Interpretation clarifies
that an entity is required to recognize a liability for the fair
value of a conditional asset retirement obligation when incurred
if the liabilitys fair value can be reasonably estimated.
The provisions of this pronouncement are effective for fiscal
years ending after December 15, 2005. The Company does not
expect the adoption of Interpretation No. 47 will have any
material financial statement impact.
In September 2005, the FASB issued SFAS No. 154,
Accounting Changes and Error Corrections, a replacement
of APB Opinion No. 20 and FASB Statement No. 3. The
statement applies to all voluntary changes in accounting
principle, and changes the requirements for accounting for and
reporting of a change in accounting principle.
SFAS No. 154 requires retrospective application to
prior periods financial statements of a voluntary change
in accounting principle unless it is impracticable.
SFAS No. 154 is effective for accounting changes and
corrections of errors made in fiscal years beginning after
December 15, 2005. Earlier application is permitted for
accounting changes and corrections of errors made occurring in
fiscal years beginning after September 1, 2005. The
statement does not change the transition provisions of any
existing accounting pronouncements, including those that are in
a transition phase as of the effective date of this statement.
The Company does not expect the adoption of
SFAS No. 154 to have a material effect on its combined
financial statements.
F-112
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Condensed Combined Financial Statements
September 30, 2005 and 2004 (Continued)
(Unaudited)
On October 26, 2005, the coal reserves and coal mining
operations of the Company were acquired by Alpha Natural
Resources, Inc. and certain subsidiaries (Alpha) for $35,200,000
in cash, $221,000,000 in promissory notes, of which $181,100,000
was paid on November 2, 2005 and $39,900,000 is due on
January 15, 2006, and 2,180,233 shares of the
Alphas common stock valued at approximately $53,200,000.
The purchase price is subject to a post-closing adjustment based
on working capital levels. The adjustment consisted of the
purchase of the outstanding capital stock of White Flame Energy,
Inc., Twin Star Mining, Inc. and Nicewonder Contracting, Inc.,
the equity interests of Powers Shop, LLC and Buchanan Energy,
LLC and substantially all of the assets of Mate Creek Energy of
W. Va., Inc. and Virginia Energy Company, and the acquisition of
Premium Energy, Inc. by merger.
F-113
Independent Auditors Report
The Board of Directors
The Combined Entities of The Nicewonder Coal Group:
We have audited the accompanying combined balance sheets of The
Combined Entities of The Nicewonder Coal Group (the Company) as
of December 31, 2004, 2003 and 2002, and the related
combined statements of income, stockholders equity and
members equity and comprehensive income, and cash flows
for the years then ended. These combined financial statements
are the responsibility of the Companys management. Our
responsibility is to express an opinion on these combined
financial statements based on our audits.
We conducted our audits 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 consideration
of internal control over financial reporting as a basis for
designing audit procedures that are appropriate in the
circumstances, but not for the purpose of expressing an opinion
on the effectiveness of the Companys internal control over
financial reporting. Accordingly, we express no such opinion. An
audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that
our audits provide a reasonable basis for our opinion.
In our opinion, the combined financial statements referred to
above present fairly, in all material respects, the financial
position of The Combined Entities of The Nicewonder Coal Group
as of December 31, 2004, 2003 and 2002, and the results of
their operations and their cash flows for the years then ended
in conformity with accounting principles generally accepted in
the Unites States of America.
As discussed in note 2(h) to the combined financial
statements, the Company adopted the provisions of FASB Statement
No. 143, Accounting for Asset Retirement
Obligations, effective January 1, 2003.
/s/ KPMG LLP
Roanoke, Virginia
September 30, 2005
F-114
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Combined Balance Sheets
December 31, 2004, 2003 and 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
ASSETS |
Current assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
12,707,479 |
|
|
|
1,786,881 |
|
|
|
3,823,424 |
|
|
Trade accounts receivable
|
|
|
9,555,345 |
|
|
|
5,281,716 |
|
|
|
4,468,600 |
|
|
Notes and other receivables
|
|
|
3,472,105 |
|
|
|
8,310,236 |
|
|
|
10,368,713 |
|
|
Inventories
|
|
|
6,914,783 |
|
|
|
2,861,421 |
|
|
|
2,338,578 |
|
|
Due from affiliate
|
|
|
87,674 |
|
|
|
87,658 |
|
|
|
95,846 |
|
|
Prepaid expenses and other current assets
|
|
|
1,791,141 |
|
|
|
1,794,109 |
|
|
|
1,670,157 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
34,528,527 |
|
|
|
20,122,021 |
|
|
|
22,765,318 |
|
Property, plant, and equipment, net
|
|
|
68,116,844 |
|
|
|
47,689,245 |
|
|
|
48,923,824 |
|
Other assets
|
|
|
2,911,155 |
|
|
|
2,889,650 |
|
|
|
2,930,485 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
105,556,526 |
|
|
|
70,700,916 |
|
|
|
74,619,627 |
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY AND MEMBERS
EQUITY |
Current liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current portion of long-term debt
|
|
$ |
11,467,093 |
|
|
|
9,709,979 |
|
|
|
9,716,000 |
|
|
Notes payable stockholder
|
|
|
2,093,630 |
|
|
|
6,611,173 |
|
|
|
8,771,173 |
|
|
Note payable affiliate
|
|
|
400,000 |
|
|
|
400,000 |
|
|
|
400,000 |
|
|
Trade accounts payable
|
|
|
5,480,123 |
|
|
|
3,759,047 |
|
|
|
3,547,361 |
|
|
Accrued expenses and other current liabilities
|
|
|
7,105,947 |
|
|
|
5,128,163 |
|
|
|
4,881,154 |
|
|
Due to affiliate
|
|
|
26,157 |
|
|
|
5,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
26,572,950 |
|
|
|
25,613,362 |
|
|
|
27,315,688 |
|
Long-term debt, net of current portion
|
|
|
20,767,857 |
|
|
|
6,717,081 |
|
|
|
11,575,394 |
|
Asset retirement obligation
|
|
|
8,922,800 |
|
|
|
6,591,200 |
|
|
|
|
|
Other liabilities
|
|
|
|
|
|
|
|
|
|
|
1,730,524 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
56,263,607 |
|
|
|
38,921,643 |
|
|
|
40,621,606 |
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity and members equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock, $10 par value. Authorized, issued and
outstanding 25,300 shares
|
|
|
253,000 |
|
|
|
253,000 |
|
|
|
203,000 |
|
|
|
Additional paid-in capital
|
|
|
12,248,436 |
|
|
|
12,248,436 |
|
|
|
12,248,436 |
|
|
|
Accumulated deficit
|
|
|
(6,376,611 |
) |
|
|
(15,187,848 |
) |
|
|
(15,053,797 |
) |
|
|
Accumulated other comprehensive income
|
|
|
57,641 |
|
|
|
36,434 |
|
|
|
29,872 |
|
|
|
Notes payable stockholders distributions
|
|
|
41,313,293 |
|
|
|
32,685,477 |
|
|
|
34,812,477 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
47,495,759 |
|
|
|
30,035,499 |
|
|
|
32,239,988 |
|
|
Members equity
|
|
|
1,797,160 |
|
|
|
1,743,774 |
|
|
|
1,758,033 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity and members equity
|
|
|
49,292,919 |
|
|
|
31,779,273 |
|
|
|
33,998,021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity and
members equity
|
|
$ |
105,556,526 |
|
|
|
70,700,916 |
|
|
|
74,619,627 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-115
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Combined Statements of Income
Years ended December 31, 2004, 2003 and 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal revenues
|
|
$ |
135,555,016 |
|
|
|
103,599,530 |
|
|
|
96,792,869 |
|
|
Other revenues
|
|
|
9,057,763 |
|
|
|
2,128,303 |
|
|
|
1,743,899 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
|
144,612,779 |
|
|
|
105,727,833 |
|
|
|
98,536,768 |
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of coal revenues (exclusive of items shown separately below)
|
|
|
96,798,423 |
|
|
|
85,100,015 |
|
|
|
79,841,973 |
|
|
Cost of other revenues
|
|
|
7,200,248 |
|
|
|
1,419,224 |
|
|
|
1,489,606 |
|
|
Depreciation, depletion and amortization
|
|
|
11,336,082 |
|
|
|
11,854,838 |
|
|
|
10,812,214 |
|
|
Selling, general and administrative expenses (exclusive of
depreciation and amortization shown separately above)
|
|
|
2,972,857 |
|
|
|
2,310,352 |
|
|
|
2,458,286 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
118,307,610 |
|
|
|
100,684,429 |
|
|
|
94,602,079 |
|
|
|
|
|
|
|
|
|
|
|
Gain on sale of fixed assets, net
|
|
|
40,252 |
|
|
|
1,281,535 |
|
|
|
129,662 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
26,345,421 |
|
|
|
6,324,939 |
|
|
|
4,064,351 |
|
|
|
|
|
|
|
|
|
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(1,351,178 |
) |
|
|
(1,486,843 |
) |
|
|
(1,797,549 |
) |
|
Interest income
|
|
|
160,888 |
|
|
|
245,965 |
|
|
|
545,406 |
|
|
Net realized gain on sale of marketable securities
|
|
|
|
|
|
|
|
|
|
|
970,557 |
|
|
Equity in loss of affiliate
|
|
|
(151,730 |
) |
|
|
(134,557 |
) |
|
|
(88,358 |
) |
|
Miscellaneous income (expense), net
|
|
|
(125,810 |
) |
|
|
120,056 |
|
|
|
162,039 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other expense, net
|
|
|
(1,467,830 |
) |
|
|
(1,255,379 |
) |
|
|
(207,905 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Income before cumulative effect of accounting change
|
|
|
24,877,591 |
|
|
|
5,069,560 |
|
|
|
3,856,446 |
|
Cumulative effect of accounting change
|
|
|
|
|
|
|
(459,876 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
24,877,591 |
|
|
|
4,609,684 |
|
|
|
3,856,446 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-116
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Combined Statements of Stockholders Equity and
Members Equity and Comprehensive Income
Years ended December 31, 2004, 2003 and 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity | |
|
|
|
|
|
|
| |
|
|
|
Total | |
|
|
|
|
Accumulated | |
|
Notes | |
|
|
|
|
|
Stockholders | |
|
|
|
|
Additional | |
|
|
|
Other | |
|
Payable- | |
|
Total | |
|
|
|
Equity and | |
|
|
Common | |
|
Paid-In | |
|
Accumulated | |
|
Comprehensive | |
|
Stockholders | |
|
Stockholders | |
|
Members | |
|
Members | |
|
|
Stock | |
|
Capital | |
|
Deficit | |
|
Income | |
|
Distributions | |
|
Equity | |
|
Equity | |
|
Equity | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Balances, December 31, 2001
|
|
$ |
203,000 |
|
|
|
12,248,436 |
|
|
|
(12,523,570 |
) |
|
|
635,780 |
|
|
|
33,618,077 |
|
|
|
34,181,723 |
|
|
|
1,490,360 |
|
|
|
35,672,083 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
3,069,773 |
|
|
|
|
|
|
|
|
|
|
|
3,069,773 |
|
|
|
786,673 |
|
|
|
3,856,446 |
|
|
Change in unrealized gains on securities available for sale
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(605,908 |
) |
|
|
|
|
|
|
(605,908 |
) |
|
|
|
|
|
|
(605,908 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,250,538 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note repayments
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,405,600 |
) |
|
|
(4,405,600 |
) |
|
|
|
|
|
|
(4,405,600 |
) |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
(5,600,000 |
) |
|
|
|
|
|
|
5,600,000 |
|
|
|
|
|
|
|
(519,000 |
) |
|
|
(519,000 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2002
|
|
|
203,000 |
|
|
|
12,248,436 |
|
|
|
(15,053,797 |
) |
|
|
29,872 |
|
|
|
34,812,477 |
|
|
|
32,239,988 |
|
|
|
1,758,033 |
|
|
|
33,998,021 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
4,165,949 |
|
|
|
|
|
|
|
|
|
|
|
4,165,949 |
|
|
|
443,735 |
|
|
|
4,609,684 |
|
|
Change in unrealized gains on securities available for sale
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,562 |
|
|
|
|
|
|
|
6,562 |
|
|
|
|
|
|
|
6,562 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,616,246 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Issuance of common stock
|
|
|
50,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
50,000 |
|
|
|
|
|
|
|
50,000 |
|
|
Note repayments
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(6,427,000 |
) |
|
|
(6,427,000 |
) |
|
|
|
|
|
|
(6,427,000 |
) |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
(4,300,000 |
) |
|
|
|
|
|
|
4,300,000 |
|
|
|
|
|
|
|
(457,994 |
) |
|
|
(457,994 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2003
|
|
|
253,000 |
|
|
|
12,248,436 |
|
|
|
(15,187,848 |
) |
|
|
36,434 |
|
|
|
32,685,477 |
|
|
|
30,035,499 |
|
|
|
1,743,774 |
|
|
|
31,779,273 |
|
|
Net income
|
|
|
|
|
|
|
|
|
|
|
23,611,237 |
|
|
|
|
|
|
|
|
|
|
|
23,611,237 |
|
|
|
1,266,354 |
|
|
|
24,877,591 |
|
|
Change in unrealized gains on securities available for sale
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
21,207 |
|
|
|
|
|
|
|
21,207 |
|
|
|
|
|
|
|
21,207 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
24,898,798 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note repayments
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(6,172,184 |
) |
|
|
(6,172,184 |
) |
|
|
|
|
|
|
(6,172,184 |
) |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
(14,800,000 |
) |
|
|
|
|
|
|
14,800,000 |
|
|
|
|
|
|
|
(1,212,968 |
) |
|
|
(1,212,968 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2004
|
|
$ |
253,000 |
|
|
|
12,248,436 |
|
|
|
(6,376,611 |
) |
|
|
57,641 |
|
|
|
41,313,293 |
|
|
|
47,495,759 |
|
|
|
1,797,160 |
|
|
|
49,292,919 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-117
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Combined Statements of Cash Flows
Years ended December 31, 2004, 2003 and 2002
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
24,877,591 |
|
|
|
4,609,684 |
|
|
|
3,856,446 |
|
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
11,336,082 |
|
|
|
11,854,838 |
|
|
|
10,812,214 |
|
|
|
Equity in loss of affiliate
|
|
|
151,730 |
|
|
|
134,557 |
|
|
|
88,358 |
|
|
|
Net realized gain on sale of marketable securities
|
|
|
|
|
|
|
|
|
|
|
(970,557 |
) |
|
|
Cumulative effect of accounting change
|
|
|
|
|
|
|
459,876 |
|
|
|
|
|
|
|
Accretion of asset retirement obligation
|
|
|
425,600 |
|
|
|
337,400 |
|
|
|
|
|
|
|
Gain on sale of fixed assets, net
|
|
|
(40,252 |
) |
|
|
(1,281,535 |
) |
|
|
(129,662 |
) |
|
|
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Trade accounts receivable
|
|
|
(4,273,629 |
) |
|
|
(813,116 |
) |
|
|
1,436,178 |
|
|
|
|
Notes and other receivables
|
|
|
4,838,131 |
|
|
|
2,058,477 |
|
|
|
(941,731 |
) |
|
|
|
Inventories
|
|
|
(4,053,362 |
) |
|
|
(522,843 |
) |
|
|
(717,638 |
) |
|
|
|
Due from affiliate
|
|
|
(16 |
) |
|
|
8,188 |
|
|
|
273,270 |
|
|
|
|
Prepaid expenses and other current assets
|
|
|
24,175 |
|
|
|
(117,390 |
) |
|
|
407,489 |
|
|
|
|
Other assets
|
|
|
(43,235 |
) |
|
|
610,154 |
|
|
|
(137,864 |
) |
|
|
|
Trade accounts payable
|
|
|
1,721,076 |
|
|
|
211,688 |
|
|
|
832,762 |
|
|
|
|
Accrued expenses and other current liabilities
|
|
|
1,977,784 |
|
|
|
247,009 |
|
|
|
494,425 |
|
|
|
|
Due to affiliate
|
|
|
21,157 |
|
|
|
5,000 |
|
|
|
14,516 |
|
|
|
|
Other liabilities
|
|
|
|
|
|
|
|
|
|
|
539,092 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
36,962,832 |
|
|
|
17,801,987 |
|
|
|
15,857,298 |
|
|
|
|
|
|
|
|
|
|
|
Investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures, including interest capitalized
|
|
|
(1,703,880 |
) |
|
|
(2,723,453 |
) |
|
|
(3,436,347 |
) |
|
Proceeds from disposition of property, plant, and equipment
|
|
|
194,643 |
|
|
|
2,311,246 |
|
|
|
627,248 |
|
|
Investment in affiliate
|
|
|
(130,000 |
) |
|
|
(51,235 |
) |
|
|
(547,665 |
) |
|
Proceeds from sale of available for sale securities
|
|
|
|
|
|
|
|
|
|
|
1,111,328 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(1,639,237 |
) |
|
|
(463,442 |
) |
|
|
(2,245,436 |
) |
|
|
|
|
|
|
|
|
|
|
Financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Repayments on notes payable
|
|
|
|
|
|
|
|
|
|
|
(4,101,760 |
) |
|
Repayments on long-term debt
|
|
|
(12,500,302 |
) |
|
|
(10,380,094 |
) |
|
|
(9,513,446 |
) |
|
Repayments on notes payable stockholder
|
|
|
(4,517,543 |
) |
|
|
(2,160,000 |
) |
|
|
(251,974 |
) |
|
Proceeds from issuance of note payable affiliate
|
|
|
|
|
|
|
|
|
|
|
400,000 |
|
|
Proceeds from issuance of notes payable stockholder
|
|
|
|
|
|
|
|
|
|
|
4,000,000 |
|
|
Repayments on notes payable stockholders
distributions
|
|
|
(6,172,184 |
) |
|
|
(6,427,000 |
) |
|
|
(4,405,600 |
) |
|
Issuance of common stock
|
|
|
|
|
|
|
50,000 |
|
|
|
|
|
|
Distributions to owners
|
|
|
(1,212,968 |
) |
|
|
(457,994 |
) |
|
|
(519,000 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities
|
|
|
(24,402,997 |
) |
|
|
(19,375,088 |
) |
|
|
(14,391,780 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and cash equivalents
|
|
|
10,920,598 |
|
|
|
(2,036,543 |
) |
|
|
(779,918 |
) |
Cash and cash equivalents at beginning of year
|
|
|
1,786,881 |
|
|
|
3,823,424 |
|
|
|
4,603,342 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of year
|
|
$ |
12,707,479 |
|
|
|
1,786,881 |
|
|
|
3,823,424 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to combined financial statements.
F-118
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial Statements
December 31, 2004, 2003 and 2002
|
|
(1) |
Business and Basis of Presentation |
|
|
(a) |
Organization and Business |
The accompanying combined financial statements include the
accounts of the coal mining operations of The Combined Entities
of The Nicewonder Coal Group (collectively, the Company). All
affiliated companies within the group are under common
management and control.
The Company is primarily engaged in the business of extracting,
processing and marketing coal from surface mines, principally
located in West Virginia and Virginia, for sale to electric
utilities and steel producers in the United States. The Company
is also engaged in the road construction contracting business in
cooperation with the West Virginia Department of Transportation
Division of Highways that permits the Company to recover the
coal removed in the construction process.
Companies comprising the coal mining operations of the Company
are the following:
|
|
|
Mate Creek Energy of W. Va., Inc. (Mate Creek) (S-Corporation) |
|
Buchanan Energy Company, LLC (Buchanan Energy) (Limited
Liability Company) |
|
Virginia Energy Company (Virginia Energy) (S-Corporation) |
|
Nicewonder Contracting, Inc. (Nicewonder Contracting)
(S-Corporation) |
|
White Flame Energy, Inc. (White Flame Energy) (S-Corporation) |
|
Premium Energy, Inc. (Premium Energy) (S-Corporation) |
|
Twin Star Mining, Inc. (Twin Star) (S-Corporation) |
|
Powers Shop, LLC (Powers Shop) (Limited Liability Company) |
Functions performed within this group range from the very
initial stages of surveying land for mining potential,
performing surface mining of all grades and qualities of coal,
transferring coal from the mine to storage facilities, and the
selling of coal to both third and related parties.
|
|
(b) |
Principles of Combination |
The accompanying combined financial statements include the
accounts of the companies described above. All significant
intercompany accounts and transactions have been eliminated in
combination.
|
|
(2) |
Summary of Significant Accounting Policies and Practices |
|
|
(a) |
Cash and Cash Equivalents |
Cash and cash equivalents consist of cash and highly liquid,
short-term investments. Cash and cash equivalents are stated at
cost, which approximates fair market value. For purposes of the
combined statements of cash flows, the Company considers all
highly liquid debt instruments with original maturities of three
months or less to be cash equivalents. The Company maintains its
cash in high quality financial institutions. The balances, at
times, may exceed federally insured limits.
|
|
(b) |
Trade Accounts Receivable and Allowance for Doubtful
Accounts |
Trade accounts receivable are recorded at the invoiced amount
and do not bear interest. An allowance for doubtful accounts is
the Companys best estimate of the amount of probable
credit losses in the Companys existing accounts
receivable. The Company establishes provisions for losses on
accounts receivable when it is probable that all or part of the
outstanding balance will not be collected. The Company regularly
reviews collectibility and establishes or adjusts an allowance
as necessary using the specific identification method. Account
balances are charged off against an allowance after all means of
F-119
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
collection have been exhausted and the potential for recovery is
considered remote. The Company does not have any
off-balance-sheet credit exposure related to its customers.
Management has determined that trade accounts receivable as of
December 31, 2004, 2003 and 2002, are collectible and
therefore, no allowance for doubtful accounts has been
established.
Coal inventories are stated at the lower of cost or market. The
cost of coal inventories is determined based on average cost of
production. Coal is classified as inventory at the point in time
the coal is extracted from the mine and weighed at a loading
facility.
Materials and supplies inventories are valued at average cost.
|
|
(d) |
Investments in Marketable Securities |
Management determines the appropriate classification of
marketable securities at time of purchase and evaluates the
appropriateness at each balance-sheet date. As of
December 31, 2004, 2003 and 2002, the Companys
marketable securities consisted of equity securities classified
as available-for-sale.
Securities available-for-sale are carried at fair value with
unrealized gains and losses reported in other comprehensive
income. Realized gains (losses) on securities available for sale
are included in other income (expense) and, when
applicable, are reported as a reclassification adjustment in
other comprehensive income. Gains and losses on sales of
securities are determined on the specific-identification method.
Declines in the fair value of individual available-for-sale
securities below their cost that are other than temporary result
in write-downs of the individual securities to their fair value.
The related write-downs are included in earnings as realized
losses.
Investments in unconsolidated subsidiaries representing
ownership of at least 20% but less than 50% are accounted for
under the equity method. Under the equity method of accounting,
the Companys proportionate share of the investee
companys income or loss is included in the Companys
net income or loss with a corresponding increase or decrease in
the carrying value of the investment.
|
|
(f) |
Property, Plant, and Equipment |
Costs for mineral properties, mineral rights, and mine
development incurred to expand capacity of operating mines or to
develop new mines are capitalized and charged to operations on
the units-of-production method over the estimated proven and
probable reserve tons. Mine development costs include costs
incurred for site preparation and development of the mines
during the development stage. Mobile mining equipment and other
fixed assets are stated at cost and depreciated on a
straight-line basis over estimated useful lives ranging from 5
to 10 years. Buildings and improvements are depreciated on
a straight-line basis over estimated useful lives ranging from
20 to 30 years. Major repairs and betterments that
significantly extend original useful lives or improve
productivity are capitalized and depreciated over the period
benefited. Maintenance and repairs are expensed as incurred.
The Company capitalizes interest cost as a component of the cost
of mine development. Interest cost capitalized during the years
ended December 31, 2003 and 2002 was $115,733 and $76,432,
respectively. No interest was capitalized for the year ended
December 31, 2004.
F-120
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
|
|
(g) |
Impairment of Long-Lived Assets |
In accordance with Statement of Financial Accounting Standards
(SFAS) No. 144, Accounting for the Impairment or
Disposal of Long-Lived Assets, long-lived assets, such as
property, plant, equipment, and purchased intangibles subject to
amortization, are reviewed for impairment whenever events or
changes in circumstances indicate that the carrying amount of an
asset may not be recoverable. Recoverability of assets to be
held and used is measured by a comparison of the carrying amount
of an asset to estimated undiscounted future cash flows expected
to be generated by the asset. If the carrying amount of an asset
exceeds its estimated future cash flows, an impairment charge is
recognized by the amount by which the carrying amount of the
asset exceeds the fair value of the asset. Assets to be disposed
of would be separately presented in the balance sheet and
reported at the lower of the carrying amount or fair value less
costs to sell, and would no longer be depreciated. The assets
and liabilities of a disposal group classified as held for sale
would be presented separately in the appropriate asset and
liability sections of the balance sheet.
|
|
(h) |
Asset Retirement Obligation |
The Company has future obligations to reclaim properties
disturbed in conjunction with coal operations under federal and
state laws. Reclamation of disturbed acreage is performed as a
normal part of the mining process.
In June 2001, the Financial Accounting Standards Board
(FASB) issued SFAS No. 143, Accounting for
Asset Retirement Obligations. SFAS No. 143
requires the Company to record the fair value of an asset
retirement obligation as a liability in the period in which it
incurs a legal obligation associated with the retirement of
tangible long-lived assets that result from the acquisition,
construction, development, and/or normal use of the assets. In
addition, the Company records a corresponding asset that is
depreciated over the life of the asset. Subsequent to the
initial measurement of the asset retirement obligation, the
obligation is adjusted at the end of each period to reflect the
passage of time and changes in the estimated future cash flows
underlying the obligation.
The Company adopted the provisions of SFAS No. 143
effective January 1, 2003. Upon adoption, property, plant,
and equipment, net were increased by $3,750,400; asset
retirement obligations were increased by $5,940,800; other
liabilities were decreased by $1,730,524; and the cumulative
effect of the change in accounting principle of $(459,876) was
reflected in the combined statement of income for the year ended
December 31, 2003.
Prior to January 1, 2003, the estimated cost for mine
reclamation was provided for using the units-of-production
method over the economic life of the mine. Estimated reclamation
costs were subject to review by management on a regular basis
and revised when appropriate for changes in future estimated
costs and/or regulatory requirements.
Lease rights to coal lands are often acquired in exchange for
royalty payments. Advance mining royalties are advance payments
made to lessors under terms of mineral lease agreements that are
recoupable against future production. These advance payments are
deferred and charged to operations as the coal reserves are
mined. The Company regularly reviews recoverability of advance
mining royalties and establishes or adjusts an allowance for
advance mining royalties as necessary using the specific
identification method. In instances where advance payments are
not expected to be offset against future production royalties,
the Company establishes a provision for losses on the advance
payments that have been paid and the scheduled future minimum
payments are expensed and recognized as liabilities.
F-121
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
Advance royalty balances are charged off against an allowance
when the lease rights are either terminated or expire.
Management has determined that the balance of advanced royalties
as of December 31, 2004, 2003 and 2002, are recoupable
against future production royalties and therefore, no allowance
for advanced mining royalties has been established.
The Company recognizes revenue on coal sales when title passes
to the customer in accordance with the terms of the sales
agreement. Revenue from coal sales is recorded at the time of
shipment or delivery to the customer, and the customer takes
ownership and assumes risk of loss based on shipping terms.
Revenues are computed on the basis of the final adjusted per ton
price to be derived from coal sales.
Other revenues generally consist of road construction contract
revenue, mineral and gas royalties, timber sales, engineering
services revenue, and rental income. These revenues, excluding
road construction contract revenue, are recognized in the period
earned or when the service is completed.
The Company recognizes revenue on long-term road construction
contracts using the percentage-of-completion method, based upon
the percentage of cubic yards excavated to date to the current
estimate of total cubic yards to be excavated to complete each
project in process at year end. Projected losses are provided
for in their entirety in the accounting period that such losses
become evident, without reference to the completion status of
such projects. Changes in job performance, job conditions, and
estimated profitability, including those arising from contract
penalty provisions, change orders, claims and final contract
settlements may result in revisions in total cubic yards to be
excavated and earned revenues and are reflected during the
accounting period in which the facts giving rise to such
revisions become known. General and administrative expenses are
expensed as incurred.
The asset, costs and estimated earnings in excess of
billings on uncompleted contracts, represents revenues
recognized in advance of amounts billed. The liability,
billings in excess of costs and estimated earnings on
uncompleted contracts, represents billings in advance of
revenues recognized.
|
|
(k) |
Shipping and Handling Costs |
Shipping and handling costs charged to customers are included in
coal revenues. Shipping and handling costs incurred by the
Company are included in cost of coal revenues.
|
|
(l) |
Workers Compensation and Pneumoconiosis (Black Lung)
Benefits |
Workers compensation at all locations in West Virginia are
insured through the West Virginia state insurance program.
Workers compensation claims at locations in all other
states where the Company operates are covered by a third-party
insurance provider.
The Company is required by federal and state statutes to provide
benefits to employees for awards related to black lung. These
claims are covered by a third-party insurance provider in all
locations where the Company operates with the exception of West
Virginia. The Companys state black lung related claims at
all locations in West Virginia are insured through the West
Virginia state insurance program.
F-122
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
The combined financial statements contain two types of entities
for federal and state income tax purposes: corporations and
limited liability companies.
The entities which are corporations have elected to be taxed
under the provision of Subchapter S of the Internal Revenue
Code. Therefore, these corporations do not pay federal or state
corporate income taxes on their taxable income. Instead, the
stockholders of the Subchapter S corporations are liable
for individual federal and state income taxes on their
proportionate share of the corporations taxable income.
Accordingly, no provision for income taxes is included in the
accompanying combined financial statements.
Certain entities are limited liability companies, which are
taxed as partnerships for federal and state income tax purposes.
Therefore, no provisions for federal or state income taxes is
made since such taxes, if any, are the responsibility of the
members.
|
|
(n) |
New Accounting Pronouncements |
In November 2004, the Financial Accounting Standards Board
(FASB) issued Statement of Financial Accounting Standards
(SFAS) No. 151, Inventory Costs which amends
the guidance in ARB No. 43, Chapter 4 Inventory
Pricing, to clarify the accounting for abnormal amounts of
idle facility expense, freight, handling costs, and wasted
material (spoilage). Paragraph 5 of ARB 43, Chapter 4,
previously stated that under some circumstances, items such as
idle facility expense, excessive spoilage, double freight, and
rehandling costs may be so abnormal as to require treatment as
current period charges. SFAS No. 151 requires that
those items be recognized as current-period charges regardless
of whether they meet the criterion of so abnormal.
In addition, SFAS No. 151 requires that allocation of
fixed production overheads to the costs of conversion be based
on the normal capacity of the production facilities.
SFAS No. 151 shall be effective for inventory costs
incurred during fiscal years beginning after June 15, 2005.
Earlier application is permitted for inventory costs incurred
during fiscal years beginning after the date
SFAS No. 151 was issued. SFAS No. 151 shall
be applied prospectively. The Company does not expect the
adoption of SFAS No. 151 to have a material effect on
its combined financial statements.
In December 2004, the FASB issued SFAS No. 153,
Exchanges of Nonmonetary Assets, which amends Accounting
Principles Board (APB) Opinion No. 29, Accounting for
Nonmonetary Transactions. APB Opinion No. 29 is based
on the principle that exchanges of nonmonetary assets should be
measured based on the fair value of the assets exchanged. The
guidance in that Opinion, however, included certain exceptions
to that principle. SFAS No. 153 amends APB Opinion
No. 29 to eliminate the exception for nonmonetary exchanges
of similar productive assets and replaces it with a general
exception for exchanges of nonmonetary assets that do not have
commercial substance. A nonmonetary exchange has commercial
substance if the future cash flows of the entity are expected to
change significantly as a result of the exchange.
SFAS No. 153 shall be effective for nonmonetary asset
exchanges occurring in fiscal periods beginning after
June 15, 2005. Earlier application is permitted for
nonmonetary asset exchanges occurring in fiscal periods
beginning after the date SFAS No. 153 was issued.
SFAS No. 153 shall be applied prospectively. The
Company does not expect the adoption of SFAS No. 153
to have a material effect on its combined financial statements.
On March 17, 2005, the Emerging Issues Task Force
(EITF) of the FASB reached consensus on EITF Issue
No. 04-6, Accounting for Stripping Costs Incurred during
Production in the Mining Industry, and on March 30,
2005, the FASB Board ratified the consensus. The EITF reached
consensus that stripping costs incurred during the production
phase of a mine are variable production costs that should be
included in the costs of inventory produced during the period
that the stripping costs are incurred. ETIF
F-123
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
04-6 is effective for the first reporting period in fiscal years
beginning after December 15, 2005 with early adoption
permitted. The Company does not expect that the adoption of
EITF 04-6 will have any material financial statement impact.
In March 2005, the FASB issued Interpretation No. 47,
Accounting for Conditional Asset Retirement Obligations,
an interpretation of SFAS No. 143, Accounting for
Asset Retirement Obligations. This Interpretation clarifies
that an entity is required to recognize a liability for the fair
value of a conditional asset retirement obligation when incurred
if the liabilitys fair value can be reasonably estimated.
The provisions of this pronouncement are effective for fiscal
years ending after December 15, 2005. The Company does not
expect the adoption of Interpretation No. 47 will have any
material financial statement impact.
In June 2005, the FASB issued SFAS No. 154,
Accounting Changes and Error Corrections, a replacement
of APB Opinion No. 20 and FASB Statement No. 3. The
statement applies to all voluntary changes in accounting
principle, and changes the requirements for accounting for and
reporting of a change in accounting principle.
SFAS No. 154 requires retrospective application to
prior periods financial statements of a voluntary change
in accounting principle unless it is impracticable.
SFAS No. 154 is effective for accounting changes and
corrections of errors made in fiscal years beginning after
December 15, 2005. Earlier application is permitted for
accounting changes and corrections of errors made occurring in
fiscal years beginning after June 1, 2005. The statement
does not change the transition provisions of any existing
accounting pronouncements, including those that are in a
transition phase as of the effective date of this statement. The
Company does not expect the adoption of SFAS No. 154
to have a material effect on its combined financial statements.
The preparation of the combined financial statements in
conformity with accounting principles generally accepted in the
United States of America requires management to make estimates
and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities
at the date of the financial statements and the reported amounts
of revenues and expenses during the reporting period.
Significant items subject to such estimates and assumptions
include the inventories; mineral reserves; asset retirement
obligations; future cash flows associated with assets;
construction contract revenues and expenses; useful lives for
depreciation, depletion, and amortization; and fair value of
financial instruments. Due to the subjective nature of these
estimates, actual results could differ from those estimates.
|
|
(3) |
Trade Accounts Receivable |
Trade accounts receivable consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Accounts receivable, unrelated parties
|
|
$ |
2,332,587 |
|
|
|
2,623,554 |
|
|
|
1,560,713 |
|
Accounts receivable, affiliated agent
|
|
|
1,806,692 |
|
|
|
2,658,162 |
|
|
|
2,229,076 |
|
Road construction contracts receivable:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Billed
|
|
|
3,281,924 |
|
|
|
|
|
|
|
678,811 |
|
|
Unbilled
|
|
|
2,134,142 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total trade accounts receivable
|
|
$ |
9,555,345 |
|
|
|
5,281,716 |
|
|
|
4,468,600 |
|
|
|
|
|
|
|
|
|
|
|
F-124
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
|
|
(4) |
Notes and Other Receivables |
Notes and other receivables consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Notes receivable related parties
|
|
$ |
3,448,555 |
|
|
|
8,254,836 |
|
|
|
8,841,736 |
|
Interest receivable related parties
|
|
|
23,050 |
|
|
|
|
|
|
|
1,524,977 |
|
Other receivable
|
|
|
500 |
|
|
|
55,400 |
|
|
|
2,000 |
|
|
|
|
|
|
|
|
|
|
|
|
Total notes and other receivables
|
|
$ |
3,472,105 |
|
|
|
8,310,236 |
|
|
|
10,368,713 |
|
|
|
|
|
|
|
|
|
|
|
Notes receivable related parties consisted of
periodic advances to affiliated entities which at each year end
are converted to notes receivable. The notes receivable are due
on demand and have interest rates ranging from 0% to 7%. On
September 1, 2004, the then outstanding balances on certain
notes receivable from one of the affiliated entities were
canceled and new demand notes bearing interest at 3% were
received from the stockholders of that affiliated entity.
Inventories consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Raw coal
|
|
$ |
291,549 |
|
|
|
401,860 |
|
|
|
507,692 |
|
Saleable coal
|
|
|
2,387,608 |
|
|
|
508,027 |
|
|
|
495,717 |
|
Materials and supplies
|
|
|
4,235,626 |
|
|
|
1,951,534 |
|
|
|
1,335,169 |
|
|
|
|
|
|
|
|
|
|
|
|
Total inventories
|
|
$ |
6,914,783 |
|
|
|
2,861,421 |
|
|
|
2,338,578 |
|
|
|
|
|
|
|
|
|
|
|
|
|
(6) |
Prepaid Expenses and Other Current Assets |
Prepaid expenses and other current assets consisted of the
following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Prepaid insurance
|
|
$ |
654,264 |
|
|
|
612,684 |
|
|
|
572,864 |
|
Other prepaid expenses
|
|
|
170,449 |
|
|
|
146,033 |
|
|
|
77,808 |
|
Advanced mining royalties
|
|
|
195,357 |
|
|
|
77,463 |
|
|
|
230,818 |
|
Refundable excise tax claims
|
|
|
200,413 |
|
|
|
200,413 |
|
|
|
203,986 |
|
Marketable securities
|
|
|
69,424 |
|
|
|
46,718 |
|
|
|
38,823 |
|
Deferred contract costs
|
|
|
|
|
|
|
188,805 |
|
|
|
|
|
Other assets
|
|
|
501,234 |
|
|
|
521,993 |
|
|
|
545,858 |
|
|
|
|
|
|
|
|
|
|
|
|
Total prepaid expenses and other current assets
|
|
$ |
1,791,141 |
|
|
|
1,794,109 |
|
|
|
1,670,157 |
|
|
|
|
|
|
|
|
|
|
|
F-125
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
|
|
(7) |
Marketable Securities |
Following is a summary of the gross unrealized gains and losses
for marketable securities classified as available-for-sale:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Available for Sale | |
|
|
| |
|
|
|
|
Gross | |
|
Gross | |
|
|
|
|
|
|
Unrealized | |
|
Unrealized | |
|
|
|
|
Cost | |
|
Gains | |
|
Losses | |
|
Fair Value | |
|
|
| |
|
| |
|
| |
|
| |
Equity securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2004
|
|
$ |
11,783 |
|
|
|
57,641 |
|
|
|
|
|
|
|
69,424 |
|
|
December 31, 2003
|
|
|
10,284 |
|
|
|
36,434 |
|
|
|
|
|
|
|
46,718 |
|
|
December 31, 2002
|
|
|
8,951 |
|
|
|
29,872 |
|
|
|
|
|
|
|
38,823 |
|
|
|
(8) |
Property, Plant, and Equipment |
Property, plant, and equipment consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Land
|
|
$ |
1,462,712 |
|
|
|
1,337,742 |
|
|
|
1,653,825 |
|
Mineral rights
|
|
|
6,673,230 |
|
|
|
6,673,230 |
|
|
|
6,673,230 |
|
Plant and mining equipment
|
|
|
145,668,580 |
|
|
|
115,278,957 |
|
|
|
105,168,027 |
|
Vehicles
|
|
|
2,491,369 |
|
|
|
2,308,050 |
|
|
|
2,258,270 |
|
Mine development
|
|
|
6,892,172 |
|
|
|
6,641,717 |
|
|
|
5,457,365 |
|
Office equipment and software
|
|
|
130,632 |
|
|
|
118,763 |
|
|
|
118,763 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
163,318,695 |
|
|
|
132,358,459 |
|
|
|
121,329,480 |
|
Accumulated depreciation, depletion and amortization
|
|
|
(95,201,851 |
) |
|
|
(84,669,214 |
) |
|
|
(72,405,656 |
) |
|
|
|
|
|
|
|
|
|
|
|
Property, plant, and equipment, net
|
|
$ |
68,116,844 |
|
|
|
47,689,245 |
|
|
|
48,923,824 |
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization expense was
$11,336,082, $11,854,838, and $10,812,214 for the years ended
December 31, 2004, 2003 and 2002, respectively.
Other assets consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Advanced mining royalties
|
|
$ |
1,431,739 |
|
|
|
1,421,959 |
|
|
|
495,102 |
|
Escrow funds
|
|
|
1,075,032 |
|
|
|
1,040,385 |
|
|
|
1,740,745 |
|
Investment in Twisted Gun, LLC
|
|
|
354,255 |
|
|
|
375,985 |
|
|
|
459,307 |
|
Other assets
|
|
|
50,129 |
|
|
|
51,321 |
|
|
|
235,331 |
|
|
|
|
|
|
|
|
|
|
|
|
Total other assets
|
|
$ |
2,911,155 |
|
|
|
2,889,650 |
|
|
|
2,930,485 |
|
|
|
|
|
|
|
|
|
|
|
F-126
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
The Company had funds invested with a cumulative loss accounted
for under the equity method as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equity Method Investment | |
|
|
| |
|
|
Funds | |
|
Cumulative | |
|
Ownership | |
|
Percent | |
|
|
Invested | |
|
Loss | |
|
Interest | |
|
Ownership | |
|
|
| |
|
| |
|
| |
|
| |
Twisted Gun, LLC:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2004
|
|
$ |
728,900 |
|
|
|
374,645 |
|
|
|
354,255 |
|
|
|
331/3% |
|
|
December 31, 2003
|
|
|
598,900 |
|
|
|
222,915 |
|
|
|
375,985 |
|
|
|
331/3% |
|
|
December 31, 2002
|
|
|
547,665 |
|
|
|
88,358 |
|
|
|
459,307 |
|
|
|
331/3% |
|
Condensed financial information from the Companys
investment carried on the equity basis at December 31 is
summarized as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Current assets
|
|
$ |
149,066 |
|
|
|
200,691 |
|
|
|
334,059 |
|
Total assets
|
|
|
826,979 |
|
|
|
1,026,738 |
|
|
|
1,416,822 |
|
Current liabilities
|
|
|
23,585 |
|
|
|
34,445 |
|
|
|
14,238 |
|
Total liabilities
|
|
|
303,745 |
|
|
|
418,103 |
|
|
|
514,199 |
|
Members capital
|
|
|
523,234 |
|
|
|
608,635 |
|
|
|
902,623 |
|
Net sales
|
|
|
465,773 |
|
|
|
529,287 |
|
|
|
183,178 |
|
Selling, general, and administrative expenses
|
|
|
941,749 |
|
|
|
936,664 |
|
|
|
384,595 |
|
Net loss
|
|
|
(475,317 |
) |
|
|
(403,672 |
) |
|
|
(197,377 |
) |
|
|
(11) |
Notes Payable with Related Parties |
Note payable affiliate consisted of a demand note
payable to an affiliated company in the amount of $400,000,
bearing interest at 7.25%. Interest is paid monthly on the note.
Notes payable-stockholder consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Note payable to the president and majority stockholder of the
Company, due on demand and noninterest bearing
|
|
$ |
2,093,630 |
|
|
|
2,611,173 |
|
|
|
4,771,173 |
|
Note payable to the president and majority stockholder of the
Company, due on demand including interest at LIBOR plus 1.75%
(paid in 2004)
|
|
|
|
|
|
|
4,000,000 |
|
|
|
4,000,000 |
|
|
|
|
|
|
|
|
|
|
|
|
Total notes payable stockholder
|
|
$ |
2,093,630 |
|
|
|
6,611,173 |
|
|
|
8,771,173 |
|
|
|
|
|
|
|
|
|
|
|
Notes payable stockholders distributions
consisted of notes payable issued to the stockholders of the
Company in lieu of cash distributions. The notes are noninterest
bearing and are due on demand. However, each December 31,
the stockholders waive their rights to call the amounts due for
a period of 18 months. The outstanding balance of the notes
payable stockholders distributions at
December 31, 2004, 2003 and 2002 was $41,313,293,
$32,685,477 and $34,812,477, respectively. Given the nature of
these notes payable to stockholders, the notes have been
reflected as part of total stockholders equity and
members equity in the accompanying combined financial
statements.
F-127
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
|
|
(12) |
Accrued Expenses and Other Current Liabilities |
Accrued expenses and other current liabilities consisted of the
following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Wages and employee benefits
|
|
$ |
2,910,982 |
|
|
|
2,298,787 |
|
|
|
1,999,629 |
|
Taxes other than income taxes
|
|
|
2,355,496 |
|
|
|
1,995,985 |
|
|
|
2,189,172 |
|
Workers compensation insurance premium payable
|
|
|
865,363 |
|
|
|
511,078 |
|
|
|
596,930 |
|
Interest payable
|
|
|
31,484 |
|
|
|
43,667 |
|
|
|
75,088 |
|
Billings in excess of costs and estimated earnings on
uncompleted contract
|
|
|
438,173 |
|
|
|
|
|
|
|
|
|
Other liabilities
|
|
|
504,449 |
|
|
|
278,646 |
|
|
|
20,335 |
|
|
|
|
|
|
|
|
|
|
|
|
Total accrued expenses and other current liabilities
|
|
$ |
7,105,947 |
|
|
|
5,128,163 |
|
|
|
4,881,154 |
|
|
|
|
|
|
|
|
|
|
|
|
|
(13) |
Uncompleted Contract |
Information with respect to the uncompleted road construction
contract as of December 31, 2004 are summarized as follows:
|
|
|
|
|
Costs incurred on uncompleted contract
|
|
$ |
7,926,442 |
|
Estimated earnings thereon
|
|
|
|
|
|
|
|
|
|
|
|
7,926,442 |
|
Less billings to date
|
|
|
8,364,615 |
|
|
|
|
|
|
|
$ |
(438,173 |
) |
|
|
|
|
Costs and estimated earnings in excess of billings on
uncompleted contract
|
|
$ |
|
|
Billings in excess of costs and estimated earnings on
uncompleted contract
|
|
|
(438,173 |
) |
|
|
|
|
|
|
$ |
(438,173 |
) |
|
|
|
|
In May 2004, Nicewonder Contracting entered into a contract
agreement with the West Virginia Department of Transportation
Division of Highways (WVDOH) for the construction of a road
project by performing excavation services and providing subgrade
materials to assist in the construction of the road. The road
project is titled the Red Jacket Project and is part
of the King Coal Highway project in West Virginia. As part of
the agreement, Nicewonder Contracting is assisting the WVDOH by
assuming the lead role in obtaining from large tract owners
sufficient legal rights to the rights-of-ways necessary to
construct the Red Jacket Project and assisting in getting the
surface lands and rights-of-ways conveyed to WVDOH. The project
is expected to take approximately six years to complete. The Red
Jacket Project is Nicewonder Contractings only project in
progress as of December 31, 2004.
Based on the terms of the contract with WVDOH, Nicewonder
Contracting is reimbursed based on units of in-place cubic yards
excavated and associated unit costs. The road construction
project is expected to be a zero profit contract over the life
of the project. As part of the contract agreement, Nicewonder
Contracting is allowed to remove and sell any and all coal
excavated during the construction process with all coal sales
revenue recognized by Nicewonder Contracting.
F-128
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
Long-term debt consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Notes payable to Caterpillar Financial Services Corporation,
monthly payments from $7,769 to $88,316 including interest from
1.74% to 7.67%, due through January 2008, collateralized by
related equipment
|
|
$ |
15,114,379 |
|
|
|
12,079,922 |
|
|
|
16,173,777 |
|
Notes payable to General Electric Capital Corporation, monthly
payments from $12,645 to $100,726 including interest from 3.11%
to 7.45%, due through July 2010, collateralized by related
equipment
|
|
|
12,437,349 |
|
|
|
1,840,551 |
|
|
|
2,362,743 |
|
Notes payable to FCC Equipment Financing, Inc., monthly payments
from $7,509 to $17,711 including interest from 5.25% to 6.53%,
due through December 2007, collateralized by related equipment
|
|
|
1,754,095 |
|
|
|
|
|
|
|
|
|
Notes payable to Branch Banking and Trust Company, monthly
payments from approximately $11,432 to $66,797 including
interest from LIBOR (2.34% at December 31, 2004) to LIBOR
plus 3%, due through April 2008, collateralized by related
equipment
|
|
|
2,594,665 |
|
|
|
1,719,915 |
|
|
|
2,409,139 |
|
$703,144 note payable to Heartwood Forestland Fund II with
imputed interest at 5.0%, payable in two annual installments of
$351,572, due October 22, 2005
|
|
|
334,462 |
|
|
|
652,643 |
|
|
|
|
|
Notes payable to Komatsu Financial Company, paid in full in
October 2004
|
|
|
|
|
|
|
134,029 |
|
|
|
345,735 |
|
|
|
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
|
32,234,950 |
|
|
|
16,427,060 |
|
|
|
21,291,394 |
|
Less current portion of long-term debt
|
|
|
11,467,093 |
|
|
|
9,709,979 |
|
|
|
9,716,000 |
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt, net of current portion
|
|
$ |
20,767,857 |
|
|
|
6,717,081 |
|
|
|
11,575,394 |
|
|
|
|
|
|
|
|
|
|
|
Future maturities of long-term debt are as follows as of
December 31, 2004:
|
|
|
|
|
|
Year ending December 31:
|
|
|
|
|
|
2005
|
|
$ |
11,467,093 |
|
|
2006
|
|
|
9,145,646 |
|
|
2007
|
|
|
5,654,024 |
|
|
2008
|
|
|
2,596,549 |
|
|
2009
|
|
|
2,012,134 |
|
|
Thereafter
|
|
|
1,359,504 |
|
|
|
|
|
|
|
$ |
32,234,950 |
|
|
|
|
|
|
|
(15) |
Asset Retirement Obligation |
Under the Federal Surface Mining Control and Reclamation Act of
1977 and similar state statutes, mine property is required to be
restored in accordance with regulated standards. The
establishment of the asset retirement obligation accrual for
mine reclamation and mine closure costs is based on permit
F-129
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
requirements and requires various estimates and assumptions,
principally associated with costs, productivities, and timing of
expenditures. The Company periodically reviews its entire
environmental liability and makes necessary adjustments,
including permit changes, revisions to costs and productivities
to reflect current experience, and accretion related to the
liability.
At December 31, 2004 and 2003, the Company has recorded
asset retirement obligation accruals for mine reclamation and
closure costs totaling $8,922,800 and $6,591,200, respectively.
Changes in the asset retirement obligation were as follows:
|
|
|
|
|
|
Adoption of SFAS No. 143 asset retirement obligation
at January 1, 2003
|
|
$ |
5,940,800 |
|
Accretion for 2003
|
|
|
337,400 |
|
Sites added in 2003
|
|
|
313,000 |
|
|
|
|
|
|
Total asset retirement obligation at December 31, 2003
|
|
|
6,591,200 |
|
Accretion for 2004
|
|
|
425,600 |
|
Sites added in 2004
|
|
|
1,906,000 |
|
|
|
|
|
|
Total asset retirement obligation at December 31, 2004
|
|
$ |
8,922,800 |
|
|
|
|
|
|
|
(16) |
Fair Value of Financial Instruments |
The estimated fair values of financial instruments under
SFAS No. 107, Disclosures About Fair Value of
Financial Instruments, are determined based on relevant
market information. These estimates involve uncertainty and
cannot be determined with precision. The following methods and
assumptions are used to estimate the fair value of each class of
financial instrument.
Cash and Cash Equivalents, Trade Accounts Receivables,
Notes Payable, Trade Accounts Payable, and Other Current
Liabilities: The carrying amounts approximate fair value due
to the short maturity of these instruments.
Notes Receivable: The fair value approximates the
carrying value as the rates associated with the receivables are
comparable to current market rates.
Long-Term Debt: The fair value of long-term debt is based
on the current market rate of interest offered to the Company
for debt of similar maturities. The estimated fair values of
long-term debt at December 31, 2004, 2003 and 2002 was
$32,250,946, $16,531,890 and $21,851,160, respectively.
|
|
(17) |
Defined Contribution Retirement Plan |
The Company sponsors a defined contribution retirement plan
covering substantially all employees. Employer contributions,
which are 8% of covered employees compensation, totaled
$1,115,442, $1,128,972, and $920,426 for the years ended
December 31, 2004, 2003 and 2002, respectively.
F-130
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
|
|
(18) |
Related Party Transactions |
The Companys stockholders consist of individuals that are
also owners in other entities that transact business with the
Company. Amounts included in the accompanying combined
statements of income with respect to transactions with related
parties are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Management and engineering fees
|
|
$ |
1,205,204 |
|
|
|
1,143,632 |
|
|
|
1,135,796 |
|
Interest income
|
|
|
88,083 |
|
|
|
173,123 |
|
|
|
417,894 |
|
Interest expense
|
|
|
29,079 |
|
|
|
115,123 |
|
|
|
118,908 |
|
Equipment rental income
|
|
|
182,640 |
|
|
|
81,300 |
|
|
|
84,575 |
|
A large portion of the Companys coal sales and shipments
are made through an affiliated company as agent. In conjunction
with these sales, the affiliated company collects amounts due
from customers and advances funds to the Company in anticipation
of their collection and receives a commission for such services.
Commission expense incurred by the Company pursuant to this
arrangement was $1,033,290, $936,121, and $967,980 for the years
ended December 31, 2004, 2003 and 2002, respectively.
The Company leases coal mining and other equipment under
long-term operating leases with varying terms. In addition, the
Company leases mineral interests and surface rights from land
owners under various terms and royalty rates.
As of December 31, 2004, aggregate future minimum lease
payments under operating leases and minimum royalties under coal
leases were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equipment | |
|
Coal | |
|
|
|
|
Rental | |
|
Royalty | |
|
Total | |
|
|
| |
|
| |
|
| |
Year ending December 31:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005
|
|
$ |
207,983 |
|
|
|
676,000 |
|
|
|
883,983 |
|
|
2006
|
|
|
80,992 |
|
|
|
11,000 |
|
|
|
91,992 |
|
|
2007
|
|
|
|
|
|
|
11,000 |
|
|
|
11,000 |
|
|
2008
|
|
|
|
|
|
|
1,000 |
|
|
|
1,000 |
|
|
2009
|
|
|
|
|
|
|
1,000 |
|
|
|
1,000 |
|
|
Thereafter
|
|
|
|
|
|
|
10,000 |
|
|
|
10,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
288,975 |
|
|
|
710,000 |
|
|
|
998,975 |
|
|
|
|
|
|
|
|
|
|
|
The above table includes amounts due under noncancelable leases
with initial or remaining lease terms in excess of one year.
Net rent expense amounted to $2,860,054, $3,153,454, and
$3,024,283 for the years ended December 31, 2004, 2003 and
2002, respectively. Coal royalties expense amounted to
$8,905,148, $7,777,981, and $7,827,735 for the years ended
December 31, 2004, 2003 and 2002, respectively.
On November 12, 2003, White Flame Energy paid $20,000 for
the option to purchase three tracts of real property located in
Mingo County, West Virginia. On December 8, 2004, the
Company exercised the
F-131
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
option to purchase the properties, and the closing was
subsequently completed in April 2005. The total purchase price
of the properties was $370,973, including the option payment.
On April 27, 2004, Nicewonder Contracting paid $10,000 for
the option to purchase certain coal and surface portions of real
estate located in Mingo County, West Virginia. The option is for
the one-year period of after midnight of April 1, 2006, but
before midnight of April 1, 2007. The purchase price for
the property will be agreed upon by the parties within ten days
prior to the date upon which the Company exercises the option.
The Company will be given credit for the $10,000 option payment
and $53,400 paid for land purchased in 2004 in determining any
payment due on the purchase.
On August 5, 2004, Nicewonder Contracting entered into a
Coal Fines Purchase Agreement for the purchase of selected coal
fines. The agreement commences on August 5, 2004, and
continues through August 5, 2014, or an earlier date if all
coal fines have been removed. The Company has agreed to pay
$6 per ton for each ton of coal fines removed.
|
|
(c) |
Construction Contracts |
The Company had uncompleted and scheduled road construction
contracts at December 31, 2004 as follows:
|
|
|
|
|
|
|
|
Contracts in progress:
|
|
|
|
|
|
Gross contracts awarded
|
|
$ |
94,397,767 |
|
|
|
Less completed portions
|
|
|
7,926,442 |
|
|
|
|
|
|
|
|
86,471,325 |
|
Scheduled contracts
|
|
|
8,482,625 |
|
|
|
|
|
|
|
|
Totals
|
|
$ |
94,953,950 |
|
|
|
|
|
|
|
(20) |
Concentrations and Major Customers |
The Company markets its coal principally to electric utilities
in the United States and domestic steel producers. Credit is
extended based on an evaluation of the customers financial
condition and collateral is generally not required. Credit
losses are provided for in the combined financial statements and
historically have been minimal. The Company is committed under
long-term contracts to supply coal that meets certain quality
requirements at specified prices. The prices for some multi-year
contracts are adjusted based on economic indices or the contract
may include year-to-year specified price changes. Quantities
sold under some contracts may vary from year to year within
certain limits at the option of the customer.
Three of the Companys largest customers accounted for
approximately 41%, 22% and 15%, which represents approximately
$55.9 million, $29.5 million and $20.7 million,
respectively, of the Companys coal revenues for the year
ended December 31, 2004. No other single customer accounted
for more than 10% of coal revenues for the year ended
December 31, 2004.
Three of the Companys largest customers accounted for
approximately 45%, 24% and 16%, which represents approximately
$46.2 million, $25.1 million and $16.7 million,
respectively, of the Companys coal revenues for the year
ended December 31, 2003. No other single customer accounted
for more than 10% of coal revenues for the year ended
December 31, 2003.
Three of the Companys largest customers accounted for
approximately 39%, 27% and 16%, which represents approximately
$37.6 million, $26.1 million and $15.8 million,
respectively, of the Companys
F-132
THE COMBINED ENTITIES OF THE
NICEWONDER COAL GROUP
Notes to Combined Financial
Statements (Continued)
coal revenues for the year ended December 31, 2002. No
other single customer accounted for more than 10% of coal
revenues for the year ended December 31, 2002.
The Company is involved in various legal proceedings from time
to time in the normal course of business. In managements
opinion, the Company is not currently involved in any legal
proceeding which individually or in the aggregate could have a
material effect on the combined financial condition, results of
operations and/or cash flows of the Company.
|
|
(22) |
Supplemental Cash Flow Disclosures |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Cash paid for interest (net of amounts capitalized)
|
|
$ |
1,363,361 |
|
|
|
1,518,264 |
|
|
|
1,774,938 |
|
Noncash investing and financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net change in unrealized gain on securities available-for-sale
|
|
|
21,207 |
|
|
|
6,562 |
|
|
|
(605,908 |
) |
|
Property and equipment purchases financed with notes payable to
sellers
|
|
|
28,308,192 |
|
|
|
4,863,117 |
|
|
|
12,515,015 |
|
|
Noncash distributions to stockholders
|
|
|
14,800,000 |
|
|
|
4,300,000 |
|
|
|
5,600,000 |
|
|
Addition to ARO asset and liability
|
|
|
1,906,000 |
|
|
|
313,000 |
|
|
|
|
|
|
Advance mining royalty financed with note payable to seller
|
|
|
|
|
|
|
652,643 |
|
|
|
|
|
|
|
(23) |
Other Comprehensive Income (Loss) |
Other comprehensive income (loss) is reported in the combined
statements of stockholders equity and members equity
and comprehensive income. The information that follows discloses
the reclassification adjustments related to marketable
securities, available-for-sale that are included in other
comprehensive income (loss):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31 | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
2002 | |
|
|
| |
|
| |
|
| |
Unrealized net gains, on marketable securities,
available-for-sale:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net unrealized holding gains during the year
|
|
$ |
21,207 |
|
|
|
6,562 |
|
|
|
364,649 |
|
|
Reclassification adjustments for gains included in net income
|
|
|
|
|
|
|
|
|
|
|
(970,557 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Other comprehensive income (loss)
|
|
$ |
21,207 |
|
|
|
6,562 |
|
|
|
(605,908 |
) |
|
|
|
|
|
|
|
|
|
|
Subsequent to December 31, 2004 through September 30,
2005, the Company purchased approximately $19.4 million of
equipment for use in its operations. These items were financed
over various periods of time ranging from 24 to 48 months.
On September 23, 2005, Alpha Natural Resources, Inc. and
certain of its subsidiaries (Alpha) entered into definitive
purchase agreements to acquire the coal reserves and coal mining
operations of the Company. Pursuant to a series of agreements,
Alpha will acquire certain assets of Mate Creek and Virginia
Energy and all of the issued and outstanding equity interests of
Powers Shop, White Flame Energy, Twin Star, Nicewonder
Contracting, Buchanan Energy, and Premium Energy.
F-133
PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
|
|
Item 13. |
Other Expenses of Issuance and Distribution. |
The following table sets forth the costs and expenses payable in
connection with the distribution of the securities being
registered. All amounts are estimated except the Securities and
Exchange Commission registration fee.
|
|
|
|
|
Securities and Exchange Commission Registration Fee
|
|
$ |
38,606 |
|
Printing and Engraving Expenses
|
|
|
250,000 |
|
Blue Sky Fees and Expenses
|
|
|
5,000 |
|
Legal Fees
|
|
|
500,000 |
|
Accounting Fees
|
|
|
300,000 |
|
Registrar and Transfer Agent Fees
|
|
|
15,000 |
|
NASD Filing Fee
|
|
|
32,000 |
|
Miscellaneous Expenses
|
|
|
59,394 |
|
|
|
|
|
|
|
$ |
1,200,000 |
|
|
|
Item 14. |
Indemnification of Directors and Officers. |
As permitted by Section 102 of the Delaware General
Corporation Law, or the DGCL, our restated certificate of
incorporation to be effective following the closing of this
offering will include a provision that eliminates the personal
liability of our directors for monetary damages for breach of
fiduciary duty as a director.
Our restated certificate of incorporation and amended and
restated bylaws will also provide that:
|
|
|
|
|
we must indemnify our directors and officers to the fullest
extent permitted by Delaware law; |
|
|
|
we may advance expenses, as incurred, to our directors and
executive officers in connection with a legal proceeding to the
fullest extent permitted by Delaware Law; and |
|
|
|
we may indemnify our other employees and agents to the same
extent that we indemnified our officers and directors, unless
otherwise determined by our board of directors. |
|
|
|
Pursuant to Section 145(a) of the DGCL, we may indemnify
any person who was or is a party or is threatened to be made a
party to any threatened, pending or completed action, suit or
proceeding (other than an action by or in the right of the
corporation) by reason of the fact that the person is or was a
director, officer, agent or employee of our company or is or was
serving at our request as a director, officer, agent, or
employee of another corporation, partnership, joint venture,
trust or other enterprise, against expenses, including
attorneys fees, judgment, fines and amounts paid in
settlement actually and reasonably incurred by the person in
connection with such action, suit or proceeding. Pursuant to
Section 145(b) of the DGCL, the power to indemnify also
applies to actions brought by or in the right of the corporation
as well, but only to the extent of defense expenses (including
attorneys fees) actually and reasonably incurred by the
person in connection with the defense or settlement of such
action or suit. Pursuant to Section 145(b), we shall not
indemnify any person in respect of any claim, issue or matter as
to which such person shall have been adjudged to be liable to us
unless and only to the extent that the Court of Chancery or the
court in which such action or suit was brought shall determine
upon application that, despite the adjudication of liability but
in view of all the circumstances of the case, such person is
fairly and reasonably entitled to indemnity for such expenses
which the Court of Chancery or such other court shall deem
proper. The power to indemnify under Sections 145(a) and
(b) of the DGCL applies (i) if such person is
successful on the merits or otherwise in defense of any action,
suit or proceeding, or (ii) if such person acted in good
faith and in a manner he reasonably believed to be |
II-1
|
|
|
|
|
in the best interest, or not opposed to the best interest, of
the corporation, and with respect to any criminal action or
proceeding, had no reasonable cause to believe his conduct was
unlawful. |
Section 174 of the DGCL provides, among other things, that
a director, who willfully or negligently approves of an unlawful
payment of dividends or an unlawful stock purchase or
redemption, may be held liable for such actions. A director who
was either absent when the unlawful actions were approved or
dissented at the time, may avoid liability by causing his or her
dissent to such actions to be entered in the books containing
the minutes of the meetings of the board of directors at the
time such action occurred or immediately after such absent
director receives notice of the unlawful acts.
The indemnification provisions contained in our restated
certificate of incorporation and amended and restated bylaws
will not be exclusive of any other rights to which a person may
be entitled by law, agreement, vote of stockholders or
disinterested directors or otherwise. In addition, we will
maintain insurance on behalf of our directors and executive
officers insuring them against any liability asserted against
them in their capacities as directors or officers or arising out
of such status.
|
|
Item 15. |
Recent Sales of Unregistered Securities. |
Prior to the completion of the initial public offering of our
common stock and in connection with our Internal Restructuring
on February 11, 2005, (1) we issued an aggregate of
28,287,580 shares of our common stock in exchange for the
contribution of shares of common stock of Alpha NR Holding, Inc.
and interests in ANR Holdings, and (2) outstanding options
held by members of our management to purchase units of Alpha
Coal Management were converted into options to purchase up to
596,985 shares of our common stock. These issuances were
made in reliance upon Section 4(2) of the Securities Act or
under Rules 506 or Rule 701 promulgated by the SEC.
In connection with the closing of the Nicewonder Acquisition on
October 26, 2005, we issued an aggregate of 2,180,233
shares of our common stock to Don Nicewonder, John Kevin
Nicewonder, Kenneth R. Nicewonder, Kim Johnson Nicewonder
and David Lester (the Premium Energy Shareholders).
Such shares were issued in reliance on the exemption from
registration contained in Rule 506 of Regulation D
promulgated under the Securities Act and Section 4(2) of
the Securities Act. Alpha relied upon representations,
warranties and agreements of the Premium Energy Shareholders,
including their agreement with respect to restrictions on
resale, in support of the satisfaction of the conditions
contained in such exemptions. No underwriting fees or sales
commission were paid in connection with the issuance of the
shares.
|
|
Item 16. |
Exhibits and Financial Statement Schedules. |
(a) Exhibits
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
1 |
.1* |
|
Form of Underwriting Agreement |
|
2 |
.1 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Dickenson-Russell Coal Company, LLC, dated as of
October 29, 2002, as amended (Incorporated by reference to
the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
2 |
.2 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Paramont Coal Company Virginia, LLC, dated as of
October 29, 2002, as amended (Incorporated by reference to
the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
2 |
.3 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Alpha Land and Reserves, LLC, dated as of October 29,
2002, as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
II-2
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
2 |
.4 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Alpha Coal Sales Co., LLC, dated as of October 29,
2002, as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.5 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Alpha Terminal Company, LLC, dated as of October 29,
2002, as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.6 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Maxxim Rebuild Co., LLC, dated as of October 29, 2002,
as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.7 |
|
Purchase and Sale Agreement by and among El Paso CGP
Company and AMFIRE, LLC dated as of November 14, 2002, as
amended (Incorporated by reference to the Registration Statement
on Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.8 |
|
Contribution Agreement among the FRC Parties, the AMCI Parties,
ANR Holdings, LLC and the Additional Persons listed on the
signature pages dated as of March 11, 2003, as amended
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.9 |
|
Purchase and Sale Agreement made and entered into as of
January 31, 2003 by and among Alpha Land and Reserves, LLC
and CSTL, LLC (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.10 |
|
Purchase and Sale Agreement dated as of April 9, 2003 by
and between Alpha Land and Reserves, LLC and CSTL LLC
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.11 |
|
Purchase and Sale Agreement dated as of April 9, 2003 by
and between Dickenson-Russell Coal Company, LLC and WBRD LLC
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.12 |
|
Letter agreement dated April 9, 2003 among Alpha Natural
Resources, LLC, Dickenson-Russell Company, LLC, Alpha Land and
Reserves, LLC, CSTL LLC, WBRD LLC, and Natural Resources
Partners L.P. (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.13 |
|
Asset Purchase Agreement by and among S&M Mining, S&M
Mining, Inc. and AMFIRE Mining Company, LLC dated
October 29, 2003, as amended (Incorporated by reference to
the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
2 |
.14 |
|
Asset Purchase Agreement by and among DLR Coal Co., DLR Mining,
Inc. and AMFIRE Mining Company, LLC dated October 29, 2003,
as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.15 |
|
Asset Purchase Agreement by and between Mears Enterprises, Inc.
and AMFIRE Mining Company, LLC dated October 29, 2003, as
amended (Incorporated by reference to the Registration Statement
on Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
II-3
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
2 |
.16 |
|
Internal Restructuring Agreement dated as of February 11,
2005 by and among Alpha Natural Resources, Inc., Alpha NR
Ventures, Inc., ANR Holdings, LLC, the FRC Parties named
therein, the AMCI Parties named therein, Madison Capital Funding
LLC, Alpha Coal Management, LLC and the Management Members named
therein (Incorporated by reference to Exhibit 2.16 to the
Annual Report on Form 10-K of Alpha Natural Resources, Inc.
(File No. 1-32423) filed on March 30, 2005.) |
|
2 |
.17 |
|
Sixth Amendment to Contribution Agreement by and among the FRC
Parties, the AMCI Parties, ANR Holdings, LLC and Alpha Natural
Resources, Inc. (Incorporated by reference to Exhibit 2.17
to the Annual Report on Form 10-K of Alpha Natural
Resources, Inc. (File No. 1-32423) filed on March 30,
2005.) |
|
2 |
.18 |
|
Asset Purchase Agreement dated April 14, 2005, by and among
Gallup Transportation and Transloading Company, LLC, NATIONAL
KING COAL LLC and NKC Acquisition, LLC (Incorporated by
reference to Exhibit 2.1 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on April 15, 2005.) |
|
2 |
.19 |
|
Acquisition Agreement dated as of September 23, 2005 among
Alpha Natural Resources, LLC, Mate Creek Energy of W. Va., Inc.,
Virginia Energy Company, the unitholders of Powers Shop, LLC,
and the shareholders of White Flame Energy, Inc., Twin Star
Mining, Inc. and Nicewonder Contracting, Inc. (the
Acquisition Agreement) (Incorporated by reference to
Exhibit 2.1 to the Current Report on Form 8-K of Alpha
Natural Resources, Inc. (File No. 1-32423) filed on
September 26, 2005.) |
|
2 |
.20 |
|
Membership Unit Purchase Agreement dated as of
September 23, 2005 among Premium Energy, LLC and the
unitholders of Buchanan Energy Company, LLC (the
Membership Unit Purchase Agreement) (Incorporated by
reference to Exhibit 2.2 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.21 |
|
Agreement and Plan of Merger dated as of September 23, 2005
among Alpha Natural Resources, Inc., Alpha Natural Resources,
LLC, Premium Energy, LLC, Premium Energy, Inc. and the
shareholders of Premium Energy, Inc. (the Premium Energy
Shareholders) (the Merger Agreement)
(Incorporated by reference to Exhibit 2.3 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.22 |
|
Indemnification Agreement dated as of September 23, 2005
among Alpha Natural Resources, Inc., Alpha Natural Resources,
LLC, Premium Energy, LLC, the other parties to the Acquisition
Agreement, the Premium Energy Shareholders, and certain of the
unitholders of Buchanan Energy Company, LLC (Incorporated by
reference to Exhibit 2.4 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.23 |
|
Letter Agreement dated of as September 23, 2005 among Alpha
Natural Resources, Inc., Alpha Natural Resources, LLC, Premium
Energy, LLC and the other parties to the Acquisition Agreement,
the Membership Unit Purchase Agreement and the Merger Agreement
(Incorporated by reference to Exhibit 2.5 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.24 |
|
Letter Agreement dated October 26, 2005 (the Letter
Agreement) among Alpha Natural Resources, Inc., Alpha
Natural Resources, LLC, Premium Energy, LLC, Premium Energy,
Inc. and the Sellers Representative named therein amending
certain provisions of (i) the Acquisition Agreement dated
September 23, 2005, among certain parties to the Letter
Agreement and certain other parties named therein, (ii) the
Agreement and Plan of Merger dated September 23, 2005,
among the parties to the Letter Agreement and certain other
parties named therein and (iii) the Indemnification
Agreement dated September 23, 2005, among the parties to
the Letter Agreement and certain other parties named therein.
(Incorporated by reference to Exhibit 2.1 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
II-4
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
2 |
.25 |
|
Assignment of Rights Under Certain Agreements executed as of
October 26, 2005 among Alpha Natural Resources, LLC, Mate
Creek Energy, LLC, Callaway Natural Resources, Inc., Premium
Energy, LLC and Virginia Energy Company, LLC (Incorporated by
reference to Exhibit 2.2 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
3 |
.1 |
|
Restated Certificate of Incorporation of Alpha Natural
Resources, Inc. (Incorporated by reference to Exhibit 3.1
to the Annual Report on Form 10-K of Alpha Natural
Resources, Inc. (File No. 1-32423) filed on March 30,
2005.) |
|
3 |
.2 |
|
Amended and Restated Bylaws of Alpha Natural Resources, Inc.
(Incorporated by reference to Exhibit 3.2 to the Annual
Report on Form 10-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on March 30, 2005.) |
|
4 |
.1 |
|
Form of certificate of Alpha Natural Resources, Inc. common
stock (Incorporated by reference to Exhibit 4.1 to
Amendment No. 3 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on February 2, 2005.) |
|
4 |
.2 |
|
Indenture dated as of May 18, 2004 among Alpha Natural
Resources, LLC, Alpha Natural Resources Capital Corp., the
Guarantors named therein and Wells Fargo Bank, N.A., as Trustee
(Incorporated by reference to Exhibit 10.5 to the
Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
4 |
.3 |
|
First Supplemental Indenture dated as of February 1, 2005
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., the Guarantors party thereto and Wells Fargo
Bank, N.A., as Trustee (Incorporated by reference to
Exhibit 4.3 to the Annual Report on Form 10-K of Alpha
Natural Resources, Inc. (File No. 1-32423) filed on
March 30, 2005.) |
|
4 |
.4 |
|
Second Supplemental Indenture dated as of March 30, 2005
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., Alpha NR Holding, Inc., Alpha NR Ventures, Inc.,
ANR Holdings, LLC, the Guarantors party thereto and Wells Fargo
Bank, N.A., as Trustee (Incorporated by reference to
Exhibit 4.4 to the Annual Report on Form 10-K of Alpha
Natural Resources, Inc. (File No. 1-32423) filed on
March 30, 2005.) |
|
4 |
.5 |
|
Third Supplemental Indenture dated as of October 26, 2005
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., Alpha NR Holding, Inc., ANR Holdings, LLC, the
Guarantors party thereto, the Guaranteeing Subsidiaries party
thereto and Wells Fargo Bank, N.A., as Trustee (Incorporated by
reference to Exhibit 10.3 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
4 |
.6* |
|
Fourth Supplemental Indenture dated as of January 3, 2006
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., Alpha NR Holding, Inc., the Guarantors party
thereto, the Guaranteeing Subsidiaries party thereto and Wells
Fargo Bank, N.A., as Trustee |
|
5 |
.1* |
|
Opinion of Bartlit Beck Herman Palenchar & Scott LLP |
|
10 |
.1 |
|
Credit Agreement dated as of October 26, 2005, among Alpha
NR Holding, Inc., Alpha Natural Resources, LLC, the Lenders and
Issuing Banks party thereto from time to time, Citicorp
North America, Inc., as administrative agent and as
collateral agent for the Lenders and Issuing Banks, UBS
Securities LLC as syndication agent, the co-documentation agents
party thereto, Citigroup Global Markets Inc. and UBS Securities
LLC, as joint lead arrangers and joint book managers.
(Incorporated by reference to Exhibit 10.1 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
10 |
.2 |
|
Guarantee and Collateral Agreement, dated as of October 26,
2005, made by each of the Grantors as defined therein, in favor
of Citicorp North America, Inc., as administrative agent and as
collateral agent for the banks and other financial institutions
or entities from time to time parties to the Credit Agreement
and the other Secured Parties, as defined therein. (Incorporated
by reference to Exhibit 10.2 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
II-5
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
10 |
.3 |
|
Credit Agreement dated as of May 28, 2004, among ANR
Holdings, LLC, Alpha Natural Resources, LLC, the Lenders from
time to time party thereto, Citicorp North America, Inc., as
administrative agent and as collateral agent, Credit Suisse
First Boston, acting through its Cayman Islands Branch, as
syndication agent, UBS Securities LLC, as documentation agent,
Credit Suisse First Boston, acting through its Cayman Islands
Branch, UBS Securities LLC and Citigroup Global Markets Inc., as
joint lead arrangers and Credit Suisse First Boston, acting
through its Cayman Islands Branch, and UBS Securities LLC, as
joint bookrunners (the Credit Agreement)
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
10 |
.4 |
|
First Amendment, dated as of August 6, 2004, to Credit
Agreement (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
10 |
.5 |
|
Second Amendment, dated as of December 28, 2004, to Credit
Agreement (Incorporated by reference to Exhibit 10.16 to
Amendment No. 2 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on February 2, 2005.) |
|
10 |
.6 |
|
Third Amendment, dated as of January 25, 2005, to Credit
Agreement (Incorporated by reference to Exhibit 10.16 to
Amendment No. 2 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on February 2, 2005.) |
|
10 |
.7 |
|
Fourth Amendment, dated as of March 28, 2005, to Credit
Agreement (Incorporated by reference to Exhibit 10.5 to the
Annual Report on Form 10-K of Alpha Natural Resources, Inc.
(File No. 1-32423) filed on March 30, 2005.) |
|
10 |
.8 |
|
Guarantee and Collateral Agreement, dated as of May 28,
2004, made by Alpha Natural Resources, LLC, ANR Holdings, LLC
and each of the other Guarantors named therein, in favor of
Citicorp North America, Inc., as administrative agent and as
collateral agent (the Guarantee and Collateral
Agreement) (Incorporated by reference to Exhibit 10.3
to the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
10 |
.9 |
|
First Amendment, dated as of August 6, 2004 to Guarantee
and Collateral Agreement (Incorporated by reference to
Exhibit 10.4 to the Registration Statement on Form S-1
of Alpha Natural Resources, Inc. (File No. 333-121002)
filed on December 6, 2004.) |
|
10 |
.10 |
|
Second Amended and Restated Employment Agreement between Alpha
Natural Resources Services, LLC and Michael J. Quillen dated
January 28, 2005 (Incorporated by reference to
Exhibit 10.6 to Amendment No. 2 to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on February 2, 2005.) |
|
10 |
.11 |
|
Employment Agreement between Alpha Natural Resources, LLC and
D. Scott Kroh dated January 1, 2003, as amended
(Incorporated by reference to Exhibit 10.7 to the
Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
10 |
.12 |
|
Amended and Restated Stockholder Agreement dated as of
October 26, 2005, by and among Alpha Natural Resources,
Inc., the FRC Parties named therein, the AMCI Parties named
therein, Madison Capital Funding LLC, the Nicewonder Parties
named therein, and the other stockholders named therein.
(Incorporated by reference to Exhibit 10.5 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
10 |
.13 |
|
Letter agreement dated October 25, 2005, by the FRC Parties
named therein and the AMCI Parties named therein, amending
certain provisions of the Stockholder Agreement. (Incorporated
by reference to Exhibit 10.4 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
II-6
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
10 |
.14 |
|
Letter agreement dated December 8, 2005, by the FRC Parties
named therein and the AMCI Parties named therein and Alpha
Natural Resources, Inc., amending certain provisions of the
Stockholder Agreement (Incorporated by reference to
Exhibit 10.1 to the Current Report on Form 8-K of
Alpha Natural Resources, Inc. (File No. 1-32423) filed on
December 12, 2005.) |
|
10 |
.15 |
|
Alpha Natural Resources Annual Incentive Bonus (AIB) Plan (the
AIB Plan) (Incorporated by reference to
Exhibit 10.9 to Amendment No. 2 to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on February 2, 2005.) |
|
10 |
.16 |
|
Amended and Restated Alpha Coal Management LLC 2004 Long-Term
Incentive Plan (Incorporated by reference to Exhibit 10.10
to Amendment No. 2 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File No.
333-121002) filed on February 2, 2005.) |
|
10 |
.17 |
|
Alpha Natural Resources, Inc. 2005 Long-Term Incentive Plan
(Incorporated by reference to Exhibit 10.11 to Amendment
No. 2 to the Registration Statement on Form S-1 of
Alpha Natural Resources, Inc. (File No. 333-121002) filed
on February 2, 2005.) |
|
10 |
.18 |
|
Form of Alpha Natural Resources, Inc. Grantee Stock Option
Agreement for Alpha Natural Resources, Inc. 2005 Long-Term
Incentive Plan (Incorporated by reference to Exhibit 10.15
to the Annual Report on Form 10-K of Alpha Natural
Resources, Inc. (File No. 1-32423) filed on March 30,
2005.) |
|
10 |
.19 |
|
Form of Alpha Natural Resources, Inc. Restricted Stock Agreement
for Alpha Natural Resources, Inc. 2005 Long-Term Incentive Plan
(Incorporated by reference to Exhibit 4.7 to the
Registration Statement on Form S-8 of Alpha Natural
Resources, Inc. (File No. 333-127528) filed on
August 15, 2005.) |
|
10 |
.20 |
|
Amended and Restated Alpha Natural Resources, Inc. and
Subsidiaries Deferred Compensation Plan First (Incorporated by
reference to Exhibit 10.1 to the Quarterly Report on
Form 10-Q of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on August 15, 2005.) |
|
10 |
.21 |
|
Coal Mining Lease dated April 9, 2003, effective as of
April 1, 2003, by and between CSTL LLC (subsequently
renamed ACIN LLC) and Alpha Land and Reserves, LLC, as amended
(Incorporated by reference to Exhibit 10.12 to Amendment
No. 1 to the Registration Statement on Form S-1 of
Alpha Natural Resources, Inc. (File No. 333-121002) filed
on January 12, 2005.) |
|
10 |
.22 |
|
Coal Mining Lease dated April 9, 2003, effective as of
April 1, 2003, by and between WBRD LLC and
Dickenson-Russell Coal Company, LLC, as amended (Incorporated by
reference to Exhibit 10.13 to Amendment No. 1 to the
Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
January 12, 2005.) |
|
10 |
.23 |
|
Coal Mining Lease dated December 4, 2002, effective as of
December 1, 2002, by and between CSTL LLC (subsequently
renamed ACIN LLC) and Coastal Coal-West Virginia, LLC
(subsequently renamed Brooks Run Mining Company), and Lease
Assignment and Assumption Agreement made and entered into as of
March 6, 2003, by and between Brooks Run Mining Company,
LLC (formerly named Coastal Coal-West Virginia, LLC) and
Kingwood Mining Company, LLC (Incorporated by reference to
Exhibit 10.14 to Amendment No. 1 to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on January 12, 2005.) |
|
10 |
.24 |
|
Cash bonus awards paid to certain executive officers of Alpha
Natural Resources, Inc. with respect to fiscal 2004 as reported
on Alpha Natural Resources, Inc.s Current Report on
Form 8-K filed on March 4, 2005 and incorporated by
this reference |
|
10 |
.25 |
|
Base salary amounts set for Alpha Natural Resources, Inc.s
named executive officers as reported on Alpha Natural Resources,
Inc.s Current Report on Form 8-K filed on
March 4, 2005 and incorporated by this reference |
|
10 |
.26 |
|
Base salary amount set for Michael D. Brown as reported in
Item 5 of Alpha Natural Resources, Inc.s Quarterly
Report on Form 10-Q filed on November 14, 2005 and
incorporated by this reference. |
II-7
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
10 |
.27 |
|
Performance goals and target bonuses set for 2005 under the AIB
Plan for Alpha Natural Resources, Inc.s executive officers
as reported on Alpha Natural Resources, Inc.s Current
Report on Form 8-K filed on April 27, 2005 and
incorporated by this reference. |
|
10 |
.28** |
|
Summary of Retention Compensation Plan approved for certain
executive officers of Alpha Natural Resources, Inc. |
|
21 |
.1* |
|
List of Subsidiaries |
|
23 |
.1* |
|
Consent of Bartlit Beck Herman Palenchar & Scott LLP
(included as part of its opinion filed as Exhibit 5.1
hereto) |
|
23 |
.2** |
|
Consent of Marshall Miller & Associates |
|
23 |
.3* |
|
Consent of KPMG LLP |
|
23 |
.4* |
|
Consent of KPMG LLP |
|
23 |
.5* |
|
Consent of KPMG LLP |
|
23 |
.6* |
|
Consent of KPMG LLP |
|
24 |
.1** |
|
Powers of Attorney by Michael J. Quillen, David C. Stuebe, Eddie
W. Neely, E. Linn Draper, Jr., Glenn A. Eisenberg, John W.
Fox, Jr., Fritz R. Kundrun and Hans J. Mende |
|
24 |
.2** |
|
Powers of Attorney by Alex T. Krueger and William E. Macaulay |
|
|
|
|
|
Confidential treatment has been granted with respect to portions
of the exhibit. Confidential portions have been omitted from
this public filing and have been filed separately with the
Securities and Exchange Commission. |
(b) Financial Statement Schedules
Not applicable.
Insofar as indemnification for liabilities arising under the
Securities Act of 1933 may be permitted to directors, officers
and controlling persons of the registrant pursuant to the
foregoing provisions, or otherwise, the registrant has been
advised that in the opinion of the SEC such indemnification is
against public policy as expressed in the Securities Act and is,
therefore, unenforceable. In the event that a claim for
indemnification against such liabilities (other than the payment
by the registrant of expenses incurred or paid by a director,
officer or controlling person of the registrant in the
successful defense of any action, suit or proceeding) is
asserted by such director, officer or controlling person in
connection with the securities being registered, the registrant
will, unless in the opinion of its counsel the matter has been
settled by controlling precedent, submit to a court of
appropriate jurisdiction the question whether such
indemnification by it is against public policy as expressed in
the Securities Act and will be governed by the final
adjudication of such issue.
II-8
The undersigned registrant hereby undertakes that:
|
|
|
(1) For purposes of determining any liability under the
Securities Act of 1933, the information omitted from the form of
prospectus filed as part of this registration statement in
reliance upon Rule 430A and contained in a form of
prospectus filed by the registrant pursuant to
Rule 424(b)(1) or (4) or 497(h) under the Securities Act
shall be deemed to be part of this registration statement as of
the time it was declared effective. |
|
|
(2) For purposes of determining any liability under the
Securities Act of 1933, each post-effective amendment that
contains a form of prospectus shall be deemed to be a new
registration statement relating to the securities offering
therein, and the offering of such securities at that time shall
be deemed to be the initial bona fide offering thereof. |
II-9
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, the
registrant has duly caused this registration statement to be
signed on its behalf by the undersigned, thereunto duly
authorized, in the city of Abingdon, State of Virginia, on
January 6, 2006.
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ALPHA NATURAL RESOURCES, INC. |
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Title: |
Vice President, Secretary and General Counsel |
Pursuant to the requirements of the Securities Act of 1933, this
registration statement has been signed by the following persons
in the capacities indicated on January 6, 2006.
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Signature |
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Title |
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*
Michael J. Quillen |
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President, Chief Executive Officer and Director (Principal
Executive Officer) |
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*
David C. Stuebe |
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Vice President and Chief Financial Officer (Principal Financial
Officer) |
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*
Eddie W. Neely |
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Vice President, Assistant Secretary and Controller (Principal
Accounting Officer) |
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*
E. Linn Draper, Jr. |
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Director |
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*
Glenn A. Eisenberg |
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Director |
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*
John W. Fox, Jr. |
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Director |
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*
Alex T. Krueger |
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Director |
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*
Fritz R. Kundrun |
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Director |
II-10
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Signature |
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Title |
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*
William E. Macaulay |
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Director |
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*
Hans J. Mende |
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Director |
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*/s/ Vaughn R. Groves
Vaughn R. Groves
Attorney-in-Fact |
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II-11
EXHIBIT INDEX
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Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
1 |
.1* |
|
Form of Underwriting Agreement |
|
2 |
.1 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Dickenson-Russell Coal Company, LLC, dated as of
October 29, 2002, as amended (Incorporated by reference to
the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
2 |
.2 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Paramont Coal Company Virginia, LLC, dated as of
October 29, 2002, as amended (Incorporated by reference to
the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
2 |
.3 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Alpha Land and Reserves, LLC, dated as of October 29,
2002, as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.4 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Alpha Coal Sales Co., LLC, dated as of October 29,
2002, as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.5 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Alpha Terminal Company, LLC, dated as of October 29,
2002, as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.6 |
|
Asset Purchase Agreement by and between Pittston Coal Company
and Maxxim Rebuild Co., LLC, dated as of October 29, 2002,
as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.7 |
|
Purchase and Sale Agreement by and among El Paso CGP
Company and AMFIRE, LLC dated as of November 14, 2002, as
amended (Incorporated by reference to the Registration Statement
on Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.8 |
|
Contribution Agreement among the FRC Parties, the AMCI Parties,
ANR Holdings, LLC and the Additional Persons listed on the
signature pages dated as of March 11, 2003, as amended
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.9 |
|
Purchase and Sale Agreement made and entered into as of
January 31, 2003 by and among Alpha Land and Reserves, LLC
and CSTL, LLC (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.10 |
|
Purchase and Sale Agreement dated as of April 9, 2003 by
and between Alpha Land and Reserves, LLC and CSTL LLC
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.11 |
|
Purchase and Sale Agreement dated as of April 9, 2003 by
and between Dickenson-Russell Coal Company, LLC and WBRD LLC
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.12 |
|
Letter agreement dated April 9, 2003 among Alpha Natural
Resources, LLC, Dickenson-Russell Company, LLC, Alpha Land and
Reserves, LLC, CSTL LLC, WBRD LLC, and Natural Resources
Partners L.P. (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
2 |
.13 |
|
Asset Purchase Agreement by and among S&M Mining, S&M
Mining, Inc. and AMFIRE Mining Company, LLC dated
October 29, 2003, as amended (Incorporated by reference to
the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
2 |
.14 |
|
Asset Purchase Agreement by and among DLR Coal Co., DLR Mining,
Inc. and AMFIRE Mining Company, LLC dated October 29, 2003,
as amended (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
2 |
.15 |
|
Asset Purchase Agreement by and between Mears Enterprises, Inc.
and AMFIRE Mining Company, LLC dated October 29, 2003, as
amended (Incorporated by reference to the Registration Statement
on Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
2 |
.16 |
|
Internal Restructuring Agreement dated as of February 11,
2005 by and among Alpha Natural Resources, Inc., Alpha NR
Ventures, Inc., ANR Holdings, LLC, the FRC Parties named
therein, the AMCI Parties named therein, Madison Capital Funding
LLC, Alpha Coal Management, LLC and the Management Members named
therein (Incorporated by reference to Exhibit 2.16 to the
Annual Report on Form 10-K of Alpha Natural Resources, Inc.
(File No. 1-32423) filed on March 30, 2005.) |
|
2 |
.17 |
|
Sixth Amendment to Contribution Agreement by and among the FRC
Parties, the AMCI Parties, ANR Holdings, LLC and Alpha Natural
Resources, Inc. (Incorporated by reference to Exhibit 2.17
to the Annual Report on Form 10-K of Alpha Natural
Resources, Inc. (File No. 1-32423) filed on March 30,
2005.) |
|
2 |
.18 |
|
Asset Purchase Agreement dated April 14, 2005, by and among
Gallup Transportation and Transloading Company, LLC, NATIONAL
KING COAL LLC and NKC Acquisition, LLC (Incorporated by
reference to Exhibit 2.1 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on April 15, 2005.) |
|
2 |
.19 |
|
Acquisition Agreement dated as of September 23, 2005 among
Alpha Natural Resources, LLC, Mate Creek Energy of W. Va., Inc.,
Virginia Energy Company, the unitholders of Powers Shop, LLC,
and the shareholders of White Flame Energy, Inc., Twin Star
Mining, Inc. and Nicewonder Contracting, Inc. (the
Acquisition Agreement) (Incorporated by reference to
Exhibit 2.1 to the Current Report on Form 8-K of Alpha
Natural Resources, Inc. (File No. 1-32423) filed on
September 26, 2005.) |
|
2 |
.20 |
|
Membership Unit Purchase Agreement dated as of
September 23, 2005 among Premium Energy, LLC and the
unitholders of Buchanan Energy Company, LLC (the
Membership Unit Purchase Agreement) (Incorporated by
reference to Exhibit 2.2 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.21 |
|
Agreement and Plan of Merger dated as of September 23, 2005
among Alpha Natural Resources, Inc., Alpha Natural Resources,
LLC, Premium Energy, LLC, Premium Energy, Inc. and the
shareholders of Premium Energy, Inc. (the Premium Energy
Shareholders) (the Merger Agreement)
(Incorporated by reference to Exhibit 2.3 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.22 |
|
Indemnification Agreement dated as of September 23, 2005
among Alpha Natural Resources, Inc., Alpha Natural Resources,
LLC, Premium Energy, LLC, the other parties to the Acquisition
Agreement, the Premium Energy Shareholders, and certain of the
unitholders of Buchanan Energy Company, LLC (Incorporated by
reference to Exhibit 2.4 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
2 |
.23 |
|
Letter Agreement dated of as September 23, 2005 among Alpha
Natural Resources, Inc., Alpha Natural Resources, LLC, Premium
Energy, LLC and the other parties to the Acquisition Agreement,
the Membership Unit Purchase Agreement and the Merger Agreement
(Incorporated by reference to Exhibit 2.5 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on September 26, 2005.) |
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
2 |
.24 |
|
Letter Agreement dated October 26, 2005 (the Letter
Agreement) among Alpha Natural Resources, Inc., Alpha
Natural Resources, LLC, Premium Energy, LLC, Premium Energy,
Inc. and the Sellers Representative named therein amending
certain provisions of (i) the Acquisition Agreement dated
September 23, 2005, among certain parties to the Letter
Agreement and certain other parties named therein, (ii) the
Agreement and Plan of Merger dated September 23, 2005,
among the parties to the Letter Agreement and certain other
parties named therein and (iii) the Indemnification
Agreement dated September 23, 2005, among the parties to
the Letter Agreement and certain other parties named therein.
(Incorporated by reference to Exhibit 2.1 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
2 |
.25 |
|
Assignment of Rights Under Certain Agreements executed as of
October 26, 2005 among Alpha Natural Resources, LLC, Mate
Creek Energy, LLC, Callaway Natural Resources, Inc., Premium
Energy, LLC and Virginia Energy Company, LLC (Incorporated by
reference to Exhibit 2.2 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
3 |
.1 |
|
Restated Certificate of Incorporation of Alpha Natural
Resources, Inc. (Incorporated by reference to Exhibit 3.1
to the Annual Report on Form 10-K of Alpha Natural
Resources, Inc. (File No. 1-32423) filed on March 30,
2005.) |
|
3 |
.2 |
|
Amended and Restated Bylaws of Alpha Natural Resources, Inc.
(Incorporated by reference to Exhibit 3.2 to the Annual
Report on Form 10-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on March 30, 2005.) |
|
4 |
.1 |
|
Form of certificate of Alpha Natural Resources, Inc. common
stock (Incorporated by reference to Exhibit 4.1 to
Amendment No. 3 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on February 2, 2005.) |
|
4 |
.2 |
|
Indenture dated as of May 18, 2004 among Alpha Natural
Resources, LLC, Alpha Natural Resources Capital Corp., the
Guarantors named therein and Wells Fargo Bank, N.A., as Trustee
(Incorporated by reference to Exhibit 10.5 to the
Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
4 |
.3 |
|
First Supplemental Indenture dated as of February 1, 2005
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., the Guarantors party thereto and Wells Fargo
Bank, N.A., as Trustee (Incorporated by reference to
Exhibit 4.3 to the Annual Report on Form 10-K of Alpha
Natural Resources, Inc. (File No. 1-32423) filed on
March 30, 2005.) |
|
4 |
.4 |
|
Second Supplemental Indenture dated as of March 30, 2005
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., Alpha NR Holding, Inc., Alpha NR Ventures, Inc.,
ANR Holdings, LLC, the Guarantors party thereto and Wells Fargo
Bank, N.A., as Trustee (Incorporated by reference to
Exhibit 4.4 to the Annual Report on Form 10-K of Alpha
Natural Resources, Inc. (File No. 1-32423) filed on
March 30, 2005.) |
|
4 |
.5 |
|
Third Supplemental Indenture dated as of October 26, 2005
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., Alpha NR Holding, Inc., ANR Holdings, LLC, the
Guarantors party thereto, the Guaranteeing Subsidiaries party
thereto and Wells Fargo Bank, N.A., as Trustee (Incorporated by
reference to Exhibit 10.3 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
4 |
.6* |
|
Fourth Supplemental Indenture dated as of January 3, 2006
among Alpha Natural Resources, LLC, Alpha Natural Resources
Capital Corp., Alpha NR Holding, Inc., the Guarantors party
thereto, the Guaranteeing Subsidiaries party thereto and Wells
Fargo Bank, N.A., as Trustee |
|
5 |
.1* |
|
Opinion of Bartlit Beck Herman Palenchar & Scott LLP |
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
10 |
.1 |
|
Credit Agreement dated as of October 26, 2005, among Alpha
NR Holding, Inc., Alpha Natural Resources, LLC, the Lenders and
Issuing Banks party thereto from time to time, Citicorp
North America, Inc., as administrative agent and as
collateral agent for the Lenders and Issuing Banks, UBS
Securities LLC as syndication agent, the co-documentation agents
party thereto, Citigroup Global Markets Inc. and UBS Securities
LLC, as joint lead arrangers and joint book managers.
(Incorporated by reference to Exhibit 10.1 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
10 |
.2 |
|
Guarantee and Collateral Agreement, dated as of October 26,
2005, made by each of the Grantors as defined therein, in favor
of Citicorp North America, Inc., as administrative agent and as
collateral agent for the banks and other financial institutions
or entities from time to time parties to the Credit Agreement
and the other Secured Parties, as defined therein. (Incorporated
by reference to Exhibit 10.2 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
10 |
.3 |
|
Credit Agreement dated as of May 28, 2004, among ANR
Holdings, LLC, Alpha Natural Resources, LLC, the Lenders from
time to time party thereto, Citicorp North America, Inc., as
administrative agent and as collateral agent, Credit Suisse
First Boston, acting through its Cayman Islands Branch, as
syndication agent, UBS Securities LLC, as documentation agent,
Credit Suisse First Boston, acting through its Cayman Islands
Branch, UBS Securities LLC and Citigroup Global Markets Inc., as
joint lead arrangers and Credit Suisse First Boston, acting
through its Cayman Islands Branch, and UBS Securities LLC, as
joint bookrunners (the Credit Agreement)
(Incorporated by reference to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on December 6, 2004.) |
|
10 |
.4 |
|
First Amendment, dated as of August 6, 2004, to Credit
Agreement (Incorporated by reference to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on December 6, 2004.) |
|
10 |
.5 |
|
Second Amendment, dated as of December 28, 2004, to Credit
Agreement (Incorporated by reference to Exhibit 10.16 to
Amendment No. 2 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on February 2, 2005.) |
|
10 |
.6 |
|
Third Amendment, dated as of January 25, 2005, to Credit
Agreement (Incorporated by reference to Exhibit 10.16 to
Amendment No. 2 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File
No. 333-121002) filed on February 2, 2005.) |
|
10 |
.7 |
|
Fourth Amendment, dated as of March 28, 2005, to Credit
Agreement (Incorporated by reference to Exhibit 10.5 to the
Annual Report on Form 10-K of Alpha Natural Resources, Inc.
(File No. 1-32423) filed on March 30, 2005.) |
|
10 |
.8 |
|
Guarantee and Collateral Agreement, dated as of May 28,
2004, made by Alpha Natural Resources, LLC, ANR Holdings, LLC
and each of the other Guarantors named therein, in favor of
Citicorp North America, Inc., as administrative agent and as
collateral agent (the Guarantee and Collateral
Agreement) (Incorporated by reference to Exhibit 10.3
to the Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
10 |
.9 |
|
First Amendment, dated as of August 6, 2004 to Guarantee
and Collateral Agreement (Incorporated by reference to
Exhibit 10.4 to the Registration Statement on Form S-1
of Alpha Natural Resources, Inc. (File No. 333-121002)
filed on December 6, 2004.) |
|
10 |
.10 |
|
Second Amended and Restated Employment Agreement between Alpha
Natural Resources Services, LLC and Michael J. Quillen dated
January 28, 2005 (Incorporated by reference to
Exhibit 10.6 to Amendment No. 2 to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on February 2, 2005.) |
|
10 |
.11 |
|
Employment Agreement between Alpha Natural Resources, LLC and
D. Scott Kroh dated January 1, 2003, as amended
(Incorporated by reference to Exhibit 10.7 to the
Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
December 6, 2004.) |
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
10 |
.12 |
|
Amended and Restated Stockholder Agreement dated as of
October 26, 2005, by and among Alpha Natural Resources,
Inc., the FRC Parties named therein, the AMCI Parties named
therein, Madison Capital Funding LLC, the Nicewonder Parties
named therein, and the other stockholders named therein.
(Incorporated by reference to Exhibit 10.5 to the Current
Report on Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
10 |
.13 |
|
Letter agreement dated October 25, 2005, by the FRC Parties
named therein and the AMCI Parties named therein, amending
certain provisions of the Stockholder Agreement. (Incorporated
by reference to Exhibit 10.4 to the Current Report on
Form 8-K of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on October 31, 2005.) |
|
10 |
.14 |
|
Letter agreement dated December 8, 2005, by the FRC Parties
named therein and the AMCI Parties named therein and Alpha
Natural Resources, Inc., amending certain provisions of the
Stockholder Agreement (Incorporated by reference to
Exhibit 10.1 to the Current Report on Form 8-K of
Alpha Natural Resources, Inc. (File No. 1-32423) filed on
December 12, 2005.) |
|
10 |
.15 |
|
Alpha Natural Resources Annual Incentive Bonus (AIB) Plan (the
AIB Plan) (Incorporated by reference to
Exhibit 10.9 to Amendment No. 2 to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on February 2, 2005.) |
|
10 |
.16 |
|
Amended and Restated Alpha Coal Management LLC 2004 Long-Term
Incentive Plan (Incorporated by reference to Exhibit 10.10
to Amendment No. 2 to the Registration Statement on
Form S-1 of Alpha Natural Resources, Inc. (File No.
333-121002) filed on February 2, 2005.) |
|
10 |
.17 |
|
Alpha Natural Resources, Inc. 2005 Long-Term Incentive Plan
(Incorporated by reference to Exhibit 10.11 to Amendment
No. 2 to the Registration Statement on Form S-1 of
Alpha Natural Resources, Inc. (File No. 333-121002) filed
on February 2, 2005.) |
|
10 |
.18 |
|
Form of Alpha Natural Resources, Inc. Grantee Stock Option
Agreement for Alpha Natural Resources, Inc. 2005 Long-Term
Incentive Plan (Incorporated by reference to Exhibit 10.15
to the Annual Report on Form 10-K of Alpha Natural
Resources, Inc. (File No. 1-32423) filed on March 30,
2005.) |
|
10 |
.19 |
|
Form of Alpha Natural Resources, Inc. Restricted Stock Agreement
for Alpha Natural Resources, Inc. 2005 Long-Term Incentive Plan
(Incorporated by reference to Exhibit 4.7 to the
Registration Statement on Form S-8 of Alpha Natural
Resources, Inc. (File No. 333-127528) filed on
August 15, 2005.) |
|
10 |
.20 |
|
Amended and Restated Alpha Natural Resources, Inc. and
Subsidiaries Deferred Compensation Plan First (Incorporated by
reference to Exhibit 10.1 to the Quarterly Report on
Form 10-Q of Alpha Natural Resources, Inc. (File
No. 1-32423) filed on August 15, 2005.) |
|
10 |
.21 |
|
Coal Mining Lease dated April 9, 2003, effective as of
April 1, 2003, by and between CSTL LLC (subsequently
renamed ACIN LLC) and Alpha Land and Reserves, LLC, as amended
(Incorporated by reference to Exhibit 10.12 to Amendment
No. 1 to the Registration Statement on Form S-1 of
Alpha Natural Resources, Inc. (File No. 333-121002) filed
on January 12, 2005.) |
|
10 |
.22 |
|
Coal Mining Lease dated April 9, 2003, effective as of
April 1, 2003, by and between WBRD LLC and
Dickenson-Russell Coal Company, LLC, as amended (Incorporated by
reference to Exhibit 10.13 to Amendment No. 1 to the
Registration Statement on Form S-1 of Alpha Natural
Resources, Inc. (File No. 333-121002) filed on
January 12, 2005.) |
|
10 |
.23 |
|
Coal Mining Lease dated December 4, 2002, effective as of
December 1, 2002, by and between CSTL LLC (subsequently
renamed ACIN LLC) and Coastal Coal-West Virginia, LLC
(subsequently renamed Brooks Run Mining Company), and Lease
Assignment and Assumption Agreement made and entered into as of
March 6, 2003, by and between Brooks Run Mining Company,
LLC (formerly named Coastal Coal-West Virginia, LLC) and
Kingwood Mining Company, LLC (Incorporated by reference to
Exhibit 10.14 to Amendment No. 1 to the Registration
Statement on Form S-1 of Alpha Natural Resources, Inc.
(File No. 333-121002) filed on January 12, 2005.) |
|
|
|
|
|
Exhibit |
|
|
No. |
|
Description of Exhibit |
|
|
|
|
10 |
.24 |
|
Cash bonus awards paid to certain executive officers of Alpha
Natural Resources, Inc. with respect to fiscal 2004 as reported
on Alpha Natural Resources, Inc.s Current Report on
Form 8-K filed on March 4, 2005 and incorporated by
this reference |
|
10 |
.25 |
|
Base salary amounts set for Alpha Natural Resources, Inc.s
named executive officers as reported on Alpha Natural Resources,
Inc.s Current Report on Form 8-K filed on
March 4, 2005 and incorporated by this reference |
|
10 |
.26 |
|
Base salary amount set for Michael D. Brown as reported in
Item 5 of Alpha Natural Resources, Inc.s Quarterly
Report on Form 10-Q filed on November 14, 2005 and
incorporated by this reference. |
|
10 |
.27 |
|
Performance goals and target bonuses set for 2005 under the AIB
Plan for Alpha Natural Resources, Inc.s executive officers
as reported on Alpha Natural Resources, Inc.s Current
Report on Form 8-K filed on April 27, 2005 and
incorporated by this reference. |
|
10 |
.28** |
|
Summary of Retention Compensation Plan approved for certain
executive officers of Alpha Natural Resources, Inc. |
|
21 |
.1* |
|
List of Subsidiaries |
|
23 |
.1* |
|
Consent of Bartlit Beck Herman Palenchar & Scott LLP
(included as part of its opinion filed as Exhibit 5.1
hereto) |
|
23 |
.2** |
|
Consent of Marshall Miller & Associates |
|
23 |
.3* |
|
Consent of KPMG LLP |
|
23 |
.4* |
|
Consent of KPMG LLP |
|
23 |
.5* |
|
Consent of KPMG LLP |
|
23 |
.6* |
|
Consent of KPMG LLP |
|
24 |
.1** |
|
Powers of Attorney by Michael J. Quillen, David C. Stuebe, Eddie
W. Neely, E. Linn Draper, Jr., Glenn A. Eisenberg, John W.
Fox, Jr., Fritz R. Kundrun and Hans J. Mende |
|
24 |
.2** |
|
Powers of Attorney by Alex T. Krueger and William E. Macaulay |
|
|
|
|
|
Confidential treatment has been granted with respect to portions
of the exhibit. Confidential portions have been omitted from
this public filing and have been filed separately with the
Securities and Exchange Commission. |