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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934 For the Fiscal Year Ended March 31, 2001
or
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934 For the transition period from to
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Commission File Number 1-16463
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PEABODY ENERGY CORPORATION
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(Exact name of registrant as specified in its charter)
DELAWARE 13-4004153
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(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
701 MARKET STREET, ST. LOUIS, MISSOURI 63101
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(Address of principal executive offices) (Zip Code)
(314) 342-3400
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Registrant's telephone number, including area code
Securities Registered Pursuant to Section 12(b) of the Act:
Title of Each Class Name of Each Exchange on Which Registered
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Common Stock, par value $0.01 per share New York Stock Exchange
Securities Registered Pursuant to Section 12(g) of the Act: NONE
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
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Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be contained,
to the best of registrant's knowledge, in any amendment to this Form 10-K. [X]
Aggregate market value of the voting stock held by non-affiliates of the
Registrant as of May 31, 2001: Common Stock, par value $0.01 per share, $739.9
million.
Number of shares outstanding of each of the Registrant's classes of Common
Stock, as of May 31, 2001: Common Stock, par value $0.01 per share, 51.9 million
shares outstanding.
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CAUTIONARY NOTICE REGARDING FORWARD-LOOKING STATEMENTS
This document includes statements of our expectations, intentions, plans
and beliefs that constitute "forward-looking statements." These statements can
be found in "Management's Discussion and Analysis of Financial Condition and
Results of Operations," and "Business" and can often be identified by
forward-looking words such as "expect," "anticipate," "believe," "goal," "plan,"
"intend," "estimate," "may" and "will" or similar words. You should be aware
that these statements are subject to known and unknown risks, uncertainties and
other factors, that could cause actual results to differ materially from those
suggested by the forward-looking statements. You should read the following in
conjunction with "Selected Financial Data" and the financial statements and
related notes to those financial statements contained in "Financial Statements
and Supplementary Data."
PART I
ITEM 1. BUSINESS.
OVERVIEW
We are the largest private-sector coal company in the world. Excluding our
Australian operations that were sold in January 2001, we sold 181.6 million tons
of coal in the year ended March 31, 2001, or more than 16% of all U.S. coal
sales. During this period, we sold coal to more than 290 electric generating and
industrial plants, fueling the generation of more than 9% of all electricity in
the United States and 2.5% of all electricity in the world. At March 1, 2001, we
had 9.3 billion tons of proven and probable coal reserves.
We own majority interests in 34 coal operations located throughout all
major U.S. coal producing regions, with 66% of our fiscal year 2001 coal sales
shipped from the western United States and the remaining 34% from the eastern
United States. Most of our production in the western United States is low sulfur
coal from the Powder River Basin. Our overall western U.S. coal production
increased from 37.0 million tons in fiscal year 1990 to 119.7 million tons in
fiscal year 2001, representing a compounded annual growth rate of 11%. In the
west, we own and operate mines in Arizona, Colorado, Montana, New Mexico and
Wyoming. In the east, we own and operate mines in Illinois, Indiana, Kentucky
and West Virginia. We produced 77% of our fiscal year 2001 sales volume from
non-union mines.
For the year ended March 31, 2001, 93% of our sales were to U.S.
electricity generators, 3% were to the U.S. industrial sector and 4% were to
customers outside the United States. Approximately 85% of our fiscal year 2001
coal sales were under long-term contracts. As of March 31, 2001, nearly one
billion tons of our future coal production were committed under long-term
contracts, with remaining terms ranging from one to 16 years and an average
volume-weighted remaining term of four years. As a result of recent significant
improvements in coal prices, we have added long-term contracts to our portfolio
at favorable prices. Additionally, our uncommitted future production positions
us well to continue to enter into favorably priced contracts. As of March 31,
2001, we had approximately 50 million tons, 101 million tons and 129 million
tons of expected production available for sale at market-based prices in
calendar year 2002, 2003 and 2004, respectively.
We are also expanding in related energy businesses that include coal
trading, coalbed methane production, transportation-related services,
third-party coal contract restructuring and participation in the development of
coal-based generating plants.
HISTORY
Peabody, Daniels and Co. was founded in 1883 as a retail coal supplier,
entering the mining business in 1888 as Peabody & Co. with our first mine in
Illinois. In 1926, Peabody Coal Company was listed on the Chicago Stock Exchange
and, beginning in 1949, on the New York Stock Exchange. In 1955, Peabody Coal
Company, primarily an underground mine operator, merged with Sinclair Coal
Company, a major surface mining company. In 1968, Peabody Coal Company was
acquired by Kennecott Copper Company. In 1977, it was sold to Peabody Holding
Company, which was formed by a consortium of companies.
In July 1990, Hanson, PLC acquired Peabody Holding Company. In February
1997, Hanson spun off its energy-related businesses, including Eastern Group and
Peabody Holding Company, into The Energy Group, plc. The Energy Group was a
publicly traded company in the United Kingdom and its American Depository
Receipts (ADR's) were publicly traded on the New York Stock Exchange. On May 19,
1997, The Energy Group, through Peabody, purchased Citizens Power LLC, a leading
power marketer.
On May 19, 1998, Lehman Brothers Merchant Banking Partners II L.P., an
affiliate of Lehman Brothers Inc. purchased Peabody Holding Company and its
affiliates, Peabody Resources Limited (Peabody Resources) and Citizens Power
LLC.
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During the 1980s, Peabody grew through expansion and acquisition, opening
the North Antelope Mine in Wyoming's coal-rich Powder River Basin in 1983 and
the Rochelle Mine in 1985. In 1984, we acquired the West Virginia coal
properties of ARMCO Steel and the following year purchased Coal Properties Corp.
and Eastern Associated Coal Corp., which included seven operating mines and
substantial low sulfur coal reserves in West Virginia.
From 1993 to 2001, we made 16 major acquisitions. In 1993, interests in
three mines in New South Wales, Australia, were acquired from Costain Group in
anticipation of the growing Pacific Rim market for coal. The properties included
100% ownership of the Ravensworth Mine, a 50% interest in the Narama Mine and a
28.75% interest in the Warkworth Mine, subsequently increased to 43.75%. We also
subsequently developed a fourth mine, Bengalla, which began shipments in early
1999. Our interest in the Bengalla joint venture was increased from 35% to 37%
in 1998 and to 40% in 2000.
In 1993 we also acquired the Lee Ranch Mine in New Mexico. The following
year, we purchased a one-third ownership in Black Beauty Coal Company (Black
Beauty), Indiana's largest coal producer. We increased our interest in Black
Beauty to 43.3% in February 1998 and to 81.7% in January 1999. Black Beauty
acquired Catlin Coal Company in 1999 and acquired an additional 25% of Arclar
Coal Company in 2000.
In 1994, we acquired the Caballo and Rawhide mines in Wyoming's Powder
River Basin from Exxon Coal USA Inc. This acquisition, along with the expansion
of the North Antelope and Rochelle Mines, positioned Peabody as the leading
producer in the Powder River Basin, the nation's largest and fastest growing
coal region. Our sales volume from the Powder River Basin increased from 31
million tons in 1993 to 101 million tons in fiscal year 2001.
In August 1999, we purchased a 55% interest in the Moura Mine in
Queensland, Australia. The Moura Mine supplies a range of steam and
metallurgical coals to Asia-Pacific customers and operates a coalbed methane
extraction operation.
In August 2000, we sold Citizens Power, our subsidiary that marketed and
traded electric power and energy-related commodity risk management products, to
Edison Mission Energy.
On January 29, 2001, we sold our Australian operations to a subsidiary of
Rio Tinto Limited.
On April 10, 2001, we changed our name from P&L Coal Holdings Corporation
to Peabody Energy Corporation.
On May 21, 2001, we completed an initial public offering of Common Stock
and our shares began trading on the New York Stock Exchange under the symbol
"BTU."
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MINING OPERATIONS
The following provides a description of the operating characteristics of
the principal mines and reserves of each of our operating units and affiliates
in the United States.
[MAP]
Within the United States, we conduct operations in four regions: Powder
River Basin; Southwest; Appalachia; and Midwest.
POWDER RIVER BASIN OPERATIONS
We control approximately 3.0 billion tons of coal reserves in the Southern
Powder River Basin, the largest and fastest growing major U.S. coal-producing
region. We own and manage two active low sulfur, non-union surface mining
complexes in Wyoming that sold approximately 99.2 million tons of coal during
fiscal year 2001, or approximately 50% of our total coal sales. The North
Antelope/Rochelle and Caballo mines are serviced by both major western
railroads, the Burlington Northern & Santa Fe and the Union Pacific.
Our Wyoming Powder River Basin reserves are classified as surface mineable,
subbituminous coal with seam thickness varying from 70 to 105 feet. The sulfur
content of the coal in current production ranges from 0.2% to 0.4% and the heat
value ranges from 8,500 to 8,900 Btu per pound.
We also operate the Big Sky Mine in Montana in the Northern Powder River
Basin. Coal is shipped from this mine to customers in the upper Midwest by the
Burlington Northern & Santa Fe railroad.
North Antelope/Rochelle
The North Antelope/Rochelle Mine is located 65 miles south of Gillette,
Wyoming. This mine is the largest and most productive in the United States,
selling 73.1 million tons during fiscal year 2001. The North Antelope/Rochelle
Mine produces premium quality coal with a sulfur content averaging 0.2% and a
heat value ranging from 8,500 to 8,900 Btu per pound. The
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North Antelope/Rochelle Mine produces the lowest sulfur coal in the United
States, using a dragline along with six truck-and-shovel fleets. We are adding a
second dragline in 2002 to improve productivity.
Caballo
The Caballo Mine is located 20 miles south of Gillette, Wyoming. During
fiscal year 2001, it sold approximately 26.1 million tons of compliance coal.
Caballo is a truck-and-shovel operation with a coal handling system that
includes two 12,000-ton silos and two 11,000-ton silos.
Big Sky
The Big Sky Mine is located in the northern end of the Powder River Basin
near Colstrip, Montana, and uses dragline mining equipment. The mine sold 1.7
million tons of medium sulfur coal during fiscal year 2001. Coal is shipped by
rail to several major electric generating customers in the upper midwestern
United States. This mine is near the exhaustion of its economically recoverable
reserves, and we may close it in the next several years, depending upon market
and mining conditions. Hourly workers at the Big Sky Mine are members of the
United Mine Workers of America.
SOUTHWEST OPERATIONS
We own and manage four mines in the western bituminous coal region - two in
Arizona, and one in each of Colorado and New Mexico. The Colorado and Arizona
mines supply primarily compliance coal and the New Mexico mine supplies medium
sulfur coal under long-term coal supply agreements to electricity generating
stations in the region. Together, these mines sold 19.7 million tons of coal
during fiscal year 2001.
Black Mesa
The Black Mesa Mine, which is located on the Navajo Nation and Hopi Tribe
reservations in Arizona, uses two draglines and sold 4.8 million tons of coal
during fiscal year 2001. The Black Mesa Mine coal is crushed, mixed with water
and then transported 273 miles through the underground Black Mesa Pipeline
(which is owned by a third party) to the Mohave Generating Station near
Laughlin, Nevada, operated and partially owned by Southern California Edison.
The mine and the pipeline were designed to deliver coal exclusively to the
plant, which has no other source of coal. The Mohave Generating Station coal
supply agreement extends until 2005, with the customer's option to extend the
term up to an additional 15 years, subject to agreement on specified terms.
Hourly workers at this mine are members of the United Mine Workers of America.
Kayenta
The Kayenta Mine is adjacent to the Black Mesa Mine and uses three
draglines in three mining areas. It sold approximately 8.0 million tons of coal
during fiscal year 2001. The Kayenta Mine coal is crushed, then carried 17 miles
by conveyor belt to storage silos where it is loaded on to a private rail line
and transported 83 miles to the Navajo Generating Station, operated by the Salt
River Project near Page, Arizona. The mine and the railroad were designed to
deliver coal exclusively to the power plant, which has no other source of coal.
The Navajo coal supply agreement extends until 2011. Hourly workers at this mine
are members of the United Mine Workers of America.
Seneca
The Seneca Mine near Hayden, Colorado shipped 1.6 million tons of
compliance coal during fiscal year 2001, operating with two draglines in two
separate mining areas. The mine's coal is hauled by truck to the nearby Hayden
Generating Station, operated by the Public Service of Colorado, under a coal
supply agreement that extends until 2011. Hourly workers at this mine are
members of the United Mine Workers of America.
Lee Ranch Coal Company
The Lee Ranch Mine, located near Grants, New Mexico, sold approximately 5.3
million tons of medium sulfur coal during fiscal year 2001. Lee Ranch shipped
the majority of its coal to two customers in Arizona and New Mexico under coal
supply agreements extending until 2010 and 2014, respectively. Lee Ranch is a
non-union surface mine that uses a combination of dragline and truck-and-shovel
mining techniques. Lee Ranch is currently expanding its annual production
capacity by approximately 2.0 million tons that we plan to sell under long-term
agreements to two new customers.
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APPALACHIA OPERATIONS
We own and manage five operating units and related facilities in West
Virginia. During fiscal year 2001, these operations sold approximately 18.5
million tons of compliance, medium sulfur and high sulfur steam and
metallurgical coal to customers in the United States and abroad. Hourly workers
at these operations are members of the United Mine Workers of America.
Big Mountain/White's Branch Operating Unit
The Big Mountain/White's Branch Operating Unit is based near Prenter, West
Virginia. In August 2000, we closed the Robin Hood No. 9 Mine after depleting
its mineable reserves and the White's Branch Mine began production. During
fiscal year 2001, the Big Mountain No. 16, Robin Hood No. 9 and White's Branch
mines sold approximately 2.4 million tons of steam coal. Big Mountain No. 16 and
White's Branch are underground mines using continuous mining equipment.
Processed coal is loaded on the CSX railroad.
Harris Operating Unit
The Harris Operating Unit consists of the Harris No. 1 Mine near Bald Knob,
West Virginia, which sold approximately 4.2 million tons of compliance coal
during fiscal year 2001. This mine uses both longwall and continuous mining
equipment.
Rocklick Operating Unit and Contract Mines
The Rocklick preparation plant, located near Wharton, West Virginia,
processes coal produced by the Harris Mine and contract mining companies from
coal reserves that we control. This preparation plant shipped approximately 7.7
million tons of steam and metallurgical coal during fiscal year 2001, including
4.2 million tons related to the Harris Operating Unit. Processed coal is loaded
at the plant site on the CSX railroad or transferred via conveyor to our
Kopperston loadout facility and loaded on the Norfolk Southern railroad.
Wells Operating Unit
The Wells Operating Unit, in Boone County, West Virginia, sold
approximately 3.7 million tons of metallurgical and steam coal during fiscal
year 2001. The unit consists of the Lightfoot No. 2 Mine, contract mines and the
Wells Preparation Plant, located near Wharton, West Virginia. The mine uses
continuous mining equipment to produce coal from reserves we own. Processed coal
is loaded on the CSX railroad.
Federal No. 2 Mine
The Federal No. 2 Mine, near Fairview, West Virginia, uses longwall mining
equipment and shipped approximately 4.8 million tons of steam coal during fiscal
year 2001. Coal shipped from the Federal No. 2 Mine has a sulfur content only
slightly above that of medium sulfur coal and has an above average heating
content. As a result, it is more marketable than some other medium sulfur coals.
The CSX and Norfolk Southern railroads jointly serve the mine.
Kanawha Eagle Coal Joint Venture
We have a minority interest in Kanawha Eagle Coal, LLC, which owns a deep
mine, a preparation plant and barge-and-rail loading facilities near Marmet,
West Virginia. The union-free mine uses continuous mining equipment and shipped
1.1 million tons during fiscal year 2001.
MIDWEST OPERATIONS
We own and operate five mines in the midwestern United States, which
collectively sold 8.8 million tons of coal during fiscal year 2001. Our midwest
operations include three underground and two surface mines, along with five
preparation plants and four barge loading facilities, located in western
Kentucky, southern Illinois and southwestern Indiana. We ship coal from these
mines primarily to electricity generators in the midwestern United States, and
we sell some coal to industrial customers that generate their own power. Some of
our hourly workers in this region are members of the United Mine Workers of
America; however, some of our mines in this region operate union-free.
We control 16 additional mines in the midwestern United States through our
81.7% joint venture interest in Black Beauty, as discussed below.
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Black Beauty Coal Company
We own 81.7% of Black Beauty, the largest coal company in the Midwest
region, which operates ten mines in Indiana and also has interests in one mine
in east-central Illinois, four mines in southern Illinois and one mine in
western Kentucky. Together these operations sold 22.9 million tons of
compliance, medium sulfur and high sulfur steam coal during fiscal year 2001. We
purchased a one-third interest in Black Beauty in 1994, and increased our
interest to 43.3% in 1998 and 81.7% in 1999. Black Beauty Resources, Inc., owned
by certain members of Black Beauty's management team, owns the remaining
interest.
Black Beauty's principal mines include Air Quality No. 1, Farmersburg,
Francisco and two mines in Somerville, Indiana. Air Quality No. 1 is an
underground coal mine located near Monroe City, Indiana that shipped 1.7 million
tons of compliance coal during fiscal year 2001. Farmersburg is a surface mine
in Vigo and Sullivan counties in Indiana that sold 4.1 million tons of medium
sulfur coal during fiscal year 2001. Francisco, located in Gibson county,
Indiana, sold 2.2 million tons during fiscal year 2001 and the two Somerville
mines, also located in Gibson county, shipped a total of 4.8 million tons in
fiscal year 2001. All of Black Beauty's mines operate union-free.
Black Beauty owns a 75%-equity interest in Sugar Camp Coal, LLC, a 5.0
million-ton per year complex comprised of two surface mines, Wildcat Hills and
Cottage Grove, and one underground mine, Eagle Valley, located in southern
Illinois. Sugar Camp also owns Arclar Coal Company, which operates one
underground mine, Big Ridge, in southern Illinois that currently sells 1.8
million tons per year. The contract work forces at Eagle Valley and Big Ridge
are both represented under non-UMWA labor agreements.
Camp Operating Unit
The Camp Operating Unit, located near Morganfield, Kentucky, currently
operates the Camp No. 11 Mine, an underground mine, and a large preparation and
barge loading facility. The Camp No. 1 Mine exhausted its economically
recoverable reserves and ceased operations in October 2000. Together, these
operations sold 5.4 million tons of coal during fiscal year 2001. The Camp No.
11 Mine uses both longwall and continuous mining equipment. We sell most of the
production under contract to the Tennessee Valley Authority.
Midwest Operating Unit
The Midwest Operating Unit near Graham, Kentucky sold 1.3 million tons of
coal during fiscal year 2001. The unit currently includes the Gibraltar surface
mining operation, which uses truck-and-shovel equipment, and the Gibraltar
Highwall Mine, which uses continuous mining equipment. The unit used to include
the Martwick mine; however in November 2000, the Martwick Mine exhausted its
economically recoverable reserves and ceased operations, and the Gibraltar
Highwall mine began operations to replace the production. We sell coal from
these mines under contract to the Tennessee Valley Authority.
Patriot Coal Company
Patriot Coal Company operates Patriot, a surface mine, and Freedom, an
underground mine, in Henderson County, Kentucky, and sold approximately 2.1
million tons of coal during fiscal year 2001. The underground mine uses
continuous mining equipment, and the surface mine uses truck-and-shovel
equipment. Patriot Coal Company also operates a preparation plant and a dock.
These mines operate union-free.
LONG-TERM COAL SUPPLY AGREEMENTS
We currently have coal supply agreements to sell nearly one billion tons of
coal, with remaining terms ranging from one to 16 years and an average
volume-weighted remaining term of four years. For fiscal year 2001, we sold 85%
of our sales volume under coal supply agreements. During fiscal year 2001, we
sold coal to more than 290 electric generators and industrial plants in 12
countries.
We expect to continue selling a significant portion of our coal under
long-term supply agreements. Our strategy is to selectively renew, or enter into
new, long-term supply contracts when we can do so at favorable prices. Long-term
contracts may be particularly attractive in regions where market prices are
expected to remain stable, with respect to high sulfur coal that would otherwise
not be in great demand or for sales under cost-plus arrangements serving captive
power plants. Prices for coal have recently risen, particularly in the Powder
River Basin and in Appalachia, primarily due to increased prices for competing
fuels and increased demand for electricity.
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Typically, customers enter into coal supply agreements to secure reliable
sources of coal at predictable prices, while we seek stable sources of revenue
to support the investments required to open, expand and maintain or improve
productivity at the mines needed to supply these contracts. The terms of coal
supply agreements result from bidding and extensive negotiations with customers.
Consequently, the terms of these contracts typically vary significantly in many
respects, including price adjustment features, price reopener terms, coal
quality requirements, quantity parameters, flexibility and adjustment mechanics,
permitted sources of supply, treatment of environmental constraints, extension
options and force majeure, termination and assignment provisions.
Each contract sets a base price. Base prices are often adjusted at
quarterly or annual intervals for changes due to inflation and/or changes in
actual costs such as taxes, fees and royalties. The inflation adjustments are
measured by public indices, the most common of which is the implicit price
deflator for the gross domestic product as published by the Department of
Commerce. In addition, most of the contracts contain price adjustments for
changes in the laws regulating the mining, production, sale or use of coal. In
the majority of these contracts, the purchaser has the right to terminate the
contract if the price increases beyond certain limits, although we can usually
decrease the price in order to maintain the contract.
Price adjustment provisions are present in most of our long-term coal
contracts greater than three years in duration. These provisions allow either
party to commence a renegotiation of the contract price at various intervals. If
the parties do not agree on a new price, the purchaser or seller often has an
option to terminate the contract. Some agreements provide that if the parties
fail to agree on a price adjustment caused by cost increases due to changes in
applicable law and regulations, the purchaser may terminate the agreement,
subject to the payment of liquidated damages. Under some contracts, we have the
right to match lower prices offered to our customers by other suppliers.
Quality and volumes for the coal are stipulated in coal supply agreements,
and in some instances buyers have the option to vary annual or monthly volumes
if necessary. Variations to the quality and volumes of coal may lead to
adjustments in the contract price. Coal supply agreements typically stipulate
procedures for quality control, sampling and weighing. Most coal supply
agreements contain provisions requiring us to deliver coal within certain ranges
for specific coal characteristics such as heat content (Btu), sulfur, ash,
grindability and ash fusion temperature. Failure to meet these specifications
can result in economic penalties, suspension or cancellation of shipments or
termination of the contracts.
Contract provisions in some cases set out mechanisms for temporary
reductions or delays in coal volumes in the event of a force majeure, including
events such as strikes, adverse mining conditions or serious transportation
problems that affect the seller or unanticipated plant outages that may affect
the buyer. More recent contracts stipulate that this tonnage can be made up by
mutual agreement or at the discretion of the buyer. Buyers often negotiate
similar clauses covering changes in environmental laws. We often negotiate the
right to supply coal that complies with a new environmental requirement to avoid
contract termination. Coal supply agreements typically contain termination
clauses if either party fails to comply with the terms and conditions of the
contract, although most termination provisions provide the opportunity to cure
defaults.
In some of our contracts, we have a right of substitution, allowing us to
provide coal from different mines as long as the replacement coal meets quality
specifications and will be sold at the same delivered cost. Contracts usually
contain specified sampling locations: in the eastern United States,
approximately 50% of customers require that the coal is sampled and weighed at
the destination, whereas in the western United States, samples are usually taken
at the shipping source.
SALES AND MARKETING
Our sales and marketing operations include Peabody COALSALES and Peabody
COALTRADE. Through these entities, we sell coal produced by our diverse
portfolio of operations, broker coal sales of other coal producers, both as
principal and agent, trade coal and emissions allowances, and provide
transportation-related services. We also restructure third-party coal supply
agreements by acquiring a customer's right to receive coal from another coal
company under a coal supply agreement, reselling that coal, and supplying that
customer with coal from our own operations. As of March 31, 2001, we had 67
employees in our sales and marketing operations, including personnel dedicated
to performing market research, contract administration and risk management
activities.
TRANSPORTATION
Coal consumed domestically is usually sold at the mine, and transportation
costs are normally borne by the purchaser. Export coal is usually sold at the
loading port, with purchasers paying ocean freight. Producers usually pay
shipping costs from the mine to the port.
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The majority of our sales volume is shipped by rail, but a portion of our
production is shipped by other modes of transportation. For example, coal from
our Camp operating unit in Kentucky is shipped by barge to the Tennessee Valley
Authority's Cumberland plant in Tennessee. Coal from our Black Mesa Mine in
Arizona is transported by a 273-mile coal-water pipeline to the Mohave
Generating Station in southern Nevada. Coal from the Seneca Mine in Colorado is
transported by truck to a nearby electric generating plant. Other mines
transport coal by rail and barge or by rail and lake carrier on the Great Lakes.
All coal from our Powder River Basin mines is shipped by rail, and two competing
railroads, the Burlington Northern & Santa Fe and the Union Pacific, serve our
two Southern Powder River Basin mines. Approximately 8,000 unit trains are
loaded each year to accommodate the coal shipped by these mines. A unit train
generally consists of 100 to 140 cars, each of which can hold 100 to 120 tons of
coal.
Our transportation department manages the loading of trains and barges. We
believe we enjoy good relationships with the rail carriers and barge companies
due, in part, to our modern coal-loading facilities and the experience of our
transportation coordinators.
SUPPLIERS
The main types of goods we purchase are mining equipment and replacement
parts, explosives, fuel, tires and lubricants. We also purchase coal from third
parties to satisfy some of our customer contracts. The supplier base providing
these goods has been relatively consistent in recent years and we have many long
established relationships with our key suppliers. We do not believe that we are
dependent on any of our individual suppliers.
TECHNICAL INNOVATION
We place great emphasis on the application of technical innovation to
improve the mining process. This research and development effort is typically
undertaken and funded by equipment manufacturers using our input and expertise.
Our engineering staff and purchasing departments work with manufacturers to
design and produce equipment that we believe will add value to the business. For
example, we worked with a manufacturer to design larger trucks to haul
overburden and coal at various mines throughout our company. In Wyoming, we were
the first coal company to use the current, state-of-the-art 400-ton haul trucks.
We have worked with our underground equipment suppliers to develop higher
horsepower continuous mining machines, which mine the coal more effectively, and
at a lower cost per ton. We have also assisted them in the development of a
continuous haulage machine, which can be operated by one person as opposed to
the standard four-person requirement. We are the largest user of advanced coal
quality analyzers among coal producers, according to the manufacturer of this
sophisticated equipment. These analyzers allow continuous analysis of certain
coal quality parameters such as sulfur content. Their use helps ensure
consistent product quality and helps customers meet stringent air emission
requirements. We also use global positioning satellite technology extensively in
our larger surface mining operations to ensure proper mine layout. As a result
of these efforts, many of our mines have become among the most productive in the
industry. We also support the Power Systems Development Facility, a highly
efficient electric generating plant using advanced emissions reduction
technology funded primarily through the Department of Energy and operated by an
affiliate of Southern Company.
COMPETITION
The markets in which we sell our coal are highly competitive. The top 10
coal producers in the United States produce approximately 64% of total domestic
coal, although there are approximately 730 coal producers in the United States.
Our principal competitors are other large coal producers, including Arch Coal,
Inc., Kennecott Energy Co., a subsidiary of Rio Tinto, RAG AG, CONSOL Energy
Inc., AEI Resources, Inc. and Massey Energy Company, which collectively
accounted for approximately 41% of total U.S. coal production in 2000.
A number of factors beyond our control affect the markets in which we sell
our coal. Continued demand for our coal and the prices obtained by us depend
primarily on the coal consumption patterns of the electricity industries in the
United States, the availability, location, cost of transportation and price of
competing coal and other electricity generation and fuel supply sources such as
natural gas, oil, nuclear and hydroelectric. Coal consumption patterns are
affected primarily by the demand for electricity, environmental and other
governmental regulations and technological developments. We compete on the basis
of coal quality, delivered price, customer service and support and reliability.
CERTAIN LIABILITIES
We have significant long-term liabilities for reclamation, work-related
injuries and illnesses, pensions and retiree health care. In addition, labor
contracts with the United Mine Workers of America and voluntary arrangements
with non-union employees include long-term benefits, notably health care
coverage for retired and future retirees and their dependents. We provide
reserves
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for a substantial portion of these obligations. The majority of our existing
liabilities relate to our past operations, which had more mines and employees
than we currently have.
Reclamation. Reclamation liabilities primarily represent the future costs
to restore surface lands to productivity levels equal to or greater than
pre-mining conditions, as required by the Surface Mining Control and Reclamation
Act. We also record other related liabilities, such as water treatment and
environmental costs. Our long-term reclamation costs, mine-closing and other
related liabilities totaled approximately $451.3 million as of March 31, 2001,
$3.6 million of which was a current liability. Expense for fiscal year 2001 was
$4.1 million.
Workers' Compensation. These liabilities represent the actuarial estimates
for compensable, work-related injuries (traumatic claims) and occupational
disease, primarily black lung disease (pneumoconiosis). The Federal Black Lung
Benefits Act requires employers to pay black lung awards to former employees who
filed claims after June 1973. These liabilities totaled approximately $244.3
million as of March 31, 2001, $33.6 million of which was a current liability.
Expense for fiscal year 2001 was $41.4 million.
Pension-Related Provisions. Pension-related costs represent the
actuarially-estimated cost of pension benefits. Annual contributions to the
pension plans are determined by consulting actuaries based on the Employee
Retirement Income Security Act minimum funding standards and an agreement with
the Pension Benefit Guaranty Corporation. Pension-related liabilities totaled
approximately $10.7 million as of March 31, 2001, $8.1 million of which was a
current liability.
Retiree Health Care. Consistent with Statement of Financial Accounting
Standards No. 106, we record a liability representing the estimated cost of
providing retiree health care benefits to current retirees and active employees
who will retire in the future. Provisions for active employees represent the
amount recognized to date, based on their service to date; additional amounts
are provided periodically so that the total liability is accrued when the
employee retires.
A second category of retiree health care obligations represents the
liability for future contributions to the United Mine Workers of America
Combined Fund created by federal law in 1992. This multiemployer fund provides
health care benefits to a closed group of former employees who retired prior to
1976; no new retirees will be added to this group. The liability is subject to
increases or decreases in per capita health care costs, offset by the mortality
curve in this aging population of beneficiaries.
Our retiree health care liabilities totaled approximately $1,036.1 million
as of March 31, 2001, $62.0 million of which was a current liability. Expense
for fiscal year 2001 was $70.7 million. Obligations to the United Mine Workers
of America Combined Fund totaled $57.8 million as of March 31, 2001, $5.6
million of which was a current liability. Income for fiscal year 2001 was $8.0
million.
DEREGULATION OF THE ELECTRICITY GENERATION INDUSTRY
In October 1992, Congress enacted the Energy Policy Act of 1992. To
stimulate competition in the electricity market, that legislation gave wholesale
suppliers access to the transmission lines of U.S. electricity generators. In
April 1996, the Federal Energy Regulatory Commission issued the first of a
series of orders establishing rules providing for open access to electricity
transmission systems. The federal government is currently exploring a number of
options concerning utility deregulation. Individual states are also proceeding
with their own deregulation initiatives.
The pace of deregulation differs significantly from state to state. To
date, 24 states and Washington, D.C. have enacted programs leading to the
deregulation of the electricity market; 19 other states are considering similar
programs. Due to the uncertainty around the timing and implementation of
deregulation, it is difficult to predict the impact on individual electricity
generators. This uncertainty has increased due to the recent energy crisis in
California, where market inefficiencies and supply and demand imbalances have
created electricity supply shortages. The crisis has slowed deregulation
activity in other states and at the federal level.
If ultimately implemented, full-scale deregulation of the power industry is
expected to enable both industrial and residential customers to shop for the
lowest-cost supply of power and the best service available. This fundamental
change in the power industry is expected to compel electricity generators to be
more aggressive in developing and defending market share, to be more focused on
their pricing and cost structures and to be more flexible in reacting to changes
in the market.
A possible consequence of deregulation is downward pressure on fuel prices.
However, because of coal's cost advantage and because some coal-based generating
facilities are underutilized in the current regulated electricity market, we
believe that additional coal demand would arise as electricity markets are
deregulated if the most efficient coal-based power plants are operated at
greater capacity.
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EMPLOYEES
As of March 31, 2001, we and our subsidiaries had approximately 6,100
employees. Approximately 37% of our employees are affiliated with organized
labor unions, which accounted for approximately 23% of the tons we sold in the
United States during fiscal year 2001. Relations with organized labor are
important to our success and we believe our relations with employees are
satisfactory. Hourly workers at our mines in Arizona, Colorado and Montana are
represented by the United Mine Workers of America under the Western Surface
Agreement, which was ratified in 2000 and is effective through September 1,
2005. Our union labor east of the Mississippi River is also represented by the
United Mine Workers of America and is subject to the National Bituminous Coal
Wage Agreement, which is effective through December 31, 2002.
REGULATORY MATTERS
Federal, state and local authorities regulate the U.S. coal mining industry
with respect to matters such as employee health and safety, permitting and
licensing requirements, air quality standards, water pollution, plant and
wildlife protection, the reclamation and restoration of mining properties after
mining has been completed, the discharge of materials into the environment,
surface subsidence from underground mining and the effects of mining on
groundwater quality and availability. In addition, the industry is affected by
significant legislation mandating certain benefits for current and retired coal
miners. Numerous federal, state and local governmental permits and approvals are
required for mining operations. We believe that we have obtained all permits
currently required to conduct our present mining operations. We may be required
to prepare and present to federal, state or local authorities data pertaining to
the effect or impact that a proposed exploration for or production of coal may
have on the environment. These requirements could prove costly and
time-consuming, and could delay commencing or continuing exploration or
production operations. Future legislation and administrative regulations may
emphasize the protection of the environment and, as a consequence, our
activities may be more closely regulated. Such legislation and regulations, as
well as future interpretations and more rigorous enforcement of existing laws,
may require substantial increases in equipment and operating costs to us and
delays, interruptions or a termination of operations, the extent of which we
cannot predict.
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 during mining
operations occur from time to time in the industry. None of the violations to
date or the monetary penalties assessed upon us has been material.
MINE SAFETY AND HEALTH
Stringent health and safety standards have been in effect since Congress
enacted the Coal Mine Health and Safety Act of 1969. The Federal Mine Safety and
Health Act of 1977 significantly expanded the enforcement of safety and health
standards and imposed safety and health standards on all aspects of mining
operations.
Most of the states 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 regulation has a significant
effect on our operating costs, our U.S. competitors are subject to the same
degree of regulation.
Our goal is to achieve excellent safety and health performance. We measure
our success in this area primarily through the use of accident frequency rates.
We believe that a superior safety and health regime is inherently tied to
achieving our productivity and financial goals. We seek to implement this goal
by: training employees in safe work practices; openly communicating with
employees; establishing, following and improving safety standards; involving
employees in establishing safety standards; and recording, reporting and
investigating all accidents, incidents and losses to avoid reoccurrence.
BLACK LUNG
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. Less than 7% of the miners currently seeking federal black lung benefits
are awarded these benefits by the federal government. The trust fund is 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. This tax is passed on to the purchaser under many of our coal
supply agreements.
In December 2000, the Department of Labor issued new amendments to the
regulations implementing the federal black lung laws that, among other things,
establish a presumption in favor of a claimant's treating physician and limit a
coal operator's ability
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to introduce medical evidence regarding the claimant's medical condition.
Industry reports anticipate that the number of claimants who are awarded
benefits will increase significantly as will the amounts of those awards. The
National Mining Association has filed a lawsuit challenging these regulations.
The U.S. District Court of the District of Columbia issued a preliminary
injunction staying the effectiveness of the new rules. A trial on the merits was
held on June 5, 2001, and the Court has not issued its decision on the matter.
COAL INDUSTRY RETIREE HEALTH BENEFIT ACT OF 1992
The Coal Act provides for the funding of health benefits for certain United
Mine Workers of America retirees. The Coal Act established the Combined Fund
into which "signatory operators" and "related persons" are obligated to pay
annual premiums for beneficiaries. The Coal Act also created a second benefit
fund for miners who retired between July 21, 1992 and September 30, 1994 and
whose former employers are no longer in business. Companies that are liable
under the Coal Act must pay premiums to the Combined Fund. Annual payments made
by certain of our subsidiaries under the Coal Act totaled $5.1 million and $4.1
million, respectively, during fiscal years 2000 and 2001.
In October 1998, the Combined Fund sent a premium notice to all assigned
operators subject to the fund that included retroactive death benefit and health
benefit premiums dating back to February 1, 1993. On November 13, 1998, 10
employers, including two of our subsidiaries, Peabody Coal Company and Eastern
Associated Coal Corp., challenged the fund's retroactive rebilling in a lawsuit
filed in the Northern District Court of Alabama. If we are successful in this
litigation, we will be eligible for a $1.0 million credit as a reduction to
future premiums.
In 1996, the Combined Fund sued the Social Security Administration in the
District of Columbia seeking a declaration that the Social Security
Administration's original calculation of the per-beneficiary premium was proper.
Certain coal companies, but not our subsidiaries, intervened in the lawsuit. On
February 25, 2000, the federal District Court ruled in favor of the Combined
Fund. The Combined Fund has obtained an amended order and the intervenor coal
companies have appealed the court's decision. If this decision is upheld on
appeal, our subsidiaries will be required to pay an additional premium to the
Combined Fund of approximately $2.4 million.
ENVIRONMENTAL LAWS
We are subject to various federal, state and foreign environmental laws.
These laws require approval of many aspects of coal mining operations, and both
federal and state inspectors regularly visit our mines and other facilities to
ensure compliance.
Surface Mining Control and Reclamation Act
The Surface Mining Control and Reclamation Act, which is administered by
the Office of Surface Mining Reclamation and Enforcement, establishes mining,
environmental protection and reclamation standards for all aspects of surface
mining as well as many aspects of deep mining. The Surface Mining Control and
Reclamation Act and similar state statutes require, among other things, the
restoration of mined property in accordance with specified standards and an
approved reclamation plan. In addition, the Abandoned Mine Land Fund, which is
part of the Surface Mining Control and Reclamation Act, imposes a fee on all
current mining operations, the proceeds of which are used to restore mines
closed before 1977. The maximum tax is $0.35 per ton on surface-mined coal and
$0.15 per ton on deep-mined coal.
A mine operator must submit a bond or otherwise secure the performance of
these reclamation obligations. Mine operators must receive permits and permit
renewals for surface mining operations from the Office of Surface Mining
Reclamation and Enforcement or, where state regulatory agencies have adopted
federally approved state programs under the act, the appropriate state
regulatory authority. We accrue for the liability associated with all
end-of-mine reclamation on a ratable basis as the coal reserve is being mined.
All states in which we have active mining operations have achieved primary
control of enforcement through approved state programs. Although we do not
anticipate significant permit issuance or renewal problems, we cannot assure you
that our permits will be renewed or granted in the future or that permit issues
will not adversely affect operations. Under previous regulations of the act,
responsibility for any coal operator currently in violation of the act could be
imputed to other companies deemed, according to regulations, to "own or control"
the coal operator. Sanctions included being blocked from receiving new permits
and rescission or suspension of existing permits. Because of a recent federal
court action invalidating these ownership and control regulations, the scope and
potential impact of the "ownership and control" requirements on us are unclear.
The Office of Surface Mining Reclamation and Enforcement has responded to the
court action by promulgating interim regulations, which more narrowly apply the
ownership and control standards to coal companies. Although the federal action
could have, by analogy, a
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precedential effect on state regulations dealing with "ownership and control,"
which are in many instances similar to the invalidated federal regulations, it
is not certain what impact the federal court decision will have on these state
regulations.
West Virginia Mountaintop Mining
On October 20, 1999, the U.S. District Court for the Southern District of
West Virginia issued a permanent injunction against the West Virginia Department
of Environmental Protection in a mountaintop-mining lawsuit. As interpreted by
the Director of the Department of Environmental Protection, the injunction
prohibits the Department from approving any new permits that would authorize the
placement of excess soil in intermittent and perennial streams for the primary
purpose of waste (overburden) disposal. The Department also interpreted the
injunction to affect certain existing coal refuse ponds, sediment ponds and
mountaintop-mining operations.
The Department has filed an appeal of the decision with the U.S. Court of
Appeals for the Fourth Circuit. On October 29, 1999, the District Court issued a
stay of its decision pending a resolution of the appeal. In April 2001, the
Fourth Circuit overturned the District Court decision regarding the intermittent
and perennial stream issue.
The Clean Air Act
The Clean Air Act, the Clean Air Act Amendments and the corresponding state
laws that regulate the emissions of materials into the air, affect coal mining
operations both directly and indirectly. Direct impacts on coal mining and
processing operations may occur through Clean Air Act permitting requirements
and/or emission control requirements relating to particulate matter, such as
fugitive dust, including future regulation of fine particulate matter measuring
ten micrometers in diameter or smaller. The Clean Air Act indirectly affects
coal mining operations by extensively regulating the air emissions of sulfur
dioxide and other compounds, including nitrogen oxides, emitted by coal-based
electricity generating plants.
In July 1997, the EPA adopted new, more stringent National Ambient Air
Quality Standards for very fine particulate matter and ozone. As a result, some
states will be required to change their existing implementation plans to attain
and maintain compliance with the new air quality standards. Our mining
operations and electric generating customers are likely to be directly affected
when the revisions to the air quality standards are implemented by the states.
State and federal regulations relating to implementation of the new air quality
standards may restrict our ability to develop new mines or could require us to
modify our existing operations. The extent of the potential direct impact of the
new air quality standards on the coal industry will depend on the policies and
control strategies associated with the state implementation process under the
Clean Air Act, but could have a material adverse effect on our financial
condition and results of operations. The Court of Appeals for the District of
Columbia issued an opinion in May 1999 limiting the manner in which the EPA can
enforce these standards. After a request by the federal government for a
rehearing by the Court of Appeals was denied, the Supreme Court agreed in
January 2000 to review the case. On February 27, 2001, the Supreme Court found
in favor of the EPA in material part and remanded the case to the Court of
Appeals. Implementation of the fine particulate National Ambient Air Quality
Standards will occur, if at all, after the Court of Appeals disposes of any
preserved challenges to the standards and the EPA develops a new implementation
policy. The effect of this decision on us and our customers is unknown at this
time.
Title IV of the Clean Air Act Amendments places limits on sulfur dioxide
emissions from electric power generation plants. The limits set baseline
emission standards for these facilities. Reductions in emissions occurred in
Phase I in 1995 and in Phase II in 2000 and apply to all coal-based power
plants. The affected electricity generators have been able to meet these
requirements by, among other ways, switching to lower sulfur fuels, installing
pollution control devices, such as scrubbers, reducing electricity generating
levels or purchasing sulfur dioxide emission allowances. Emission sources
receive these sulfur dioxide emission allowances, which can be traded or sold to
allow other units to emit higher levels of sulfur dioxide. We cannot ascertain
the effect of these provisions of the Clean Air Act Amendments on us at this
time. We believe that implementation of Phase II has resulted in a downward
pressure on the price of higher sulfur coal, as additional coal-based electric
generating plants have complied with the restrictions of Title IV.
The Clean Air Act Amendments also require electricity generators that
currently are major sources of nitrogen oxides in moderate or higher ozone
non-attainment areas to install reasonably available control technology for
nitrogen oxides, which are precursors of ozone. In addition, the EPA recently
announced the final rules that would require 19 eastern states and Washington,
D.C. to make substantial reductions in nitrogen oxide emissions. Installation of
additional control measures required under the final rules will make it more
costly to operate coal-based electric generating plants.
In accordance with Section 126 of the Clean Air Act, eight northeastern
states filed petitions requesting the EPA to make findings and require decreases
in nitrogen oxide emissions from certain sources in certain upwind states that
might contribute to ozone nonattainment in the petitioning states. The EPA has
granted four of the eight petitions finding that certain sources are
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contributing to ozone non-attainment in certain of the petitioning states and
the EPA has proposed levels of nitrogen oxide control for the named sources. Our
customers are among the named sources and, implementation of the requirement to
install control equipment could impact the amount of coal supplied to those
customers if they decide to switch to other sources of fuel, which would result
in lower emission of nitrogen oxides. A coalition of 40 electricity generators
and power companies petitioned the U.S. Court of Appeals for the District of
Columbia to review the EPA's decision to grant the four petitions. On May 15,
2001, the Court of Appeals substantially upheld the EPA's ruling, but remanded
for reconsideration the EPA's decision to regulate certain cogeneration
facilities and the EPA's use of certain projections regarding future growth in
setting the nitrogen oxide emission limitations.
The Clean Air Act Amendments provisions for new source review require
electricity generators to install the best available control technology if they
make a major modification to a facility that results in an increase in its
potential to emit regulated pollutants. The Justice Department on behalf of the
EPA filed a number of lawsuits since November 1999, alleging that ten
electricity generators violated the new source review provisions of the Clean
Air Act Amendments at power plants in the midwestern and southern United States.
The EPA issued an administrative order alleging similar violations by the
Tennessee Valley Authority, affecting seven plants and notices of violation for
an additional eight plants owned by the affected electricity generators. Three
electricity generators have reached settlements with the Justice Department
requiring the installation of additional control equipment on selected
generating units. If the remaining electricity generators are found to be in
violation, they could be subject to civil penalties and be required to install
the required control equipment or cease operations. Our customers are among the
named electricity generators and if found not to be in compliance, the fines and
requirements to install additional control equipment could adversely affect the
amount of coal they would burn if the plant operating costs were to increase to
the point that the plants were operated less frequently.
The Clean Air Act Amendments set a national goal for the prevention of any
future, and the remedying of any existing, impairment of visibility in 156
national parks and wildlife areas across the country. Visibility in these areas
is to be returned to natural conditions by 2064 through plans that must be
developed by the states. The state plans may require the application of "Best
Available Retrofit Technology" after 2010 on sources found to be contributing to
visibility impairment of regional haze in these areas. The control technology
requirements could cause our customers to install equipment to control sulfur
dioxide and nitrogen oxide emissions. The requirement to install control
equipment could affect the amount of coal supplied to those customers if they
decide to switch to other sources of fuel to lower emission of sulfur oxides and
nitrogen oxides.
In addition, the Clean Air Act Amendments require a study of electric
generating plant emissions of certain toxic substances, including mercury, and
direct the EPA to regulate these substances, if warranted. In December 2000, the
EPA decided that mercury air emissions from power plants should be regulated.
The EPA will propose regulations by December 2003 and will issue final
regulations by December 2004. It is a possibility that future regulatory
activity may seek to reduce mercury emissions and these requirements, if
adopted, could result in reduced use of coal if electricity generators switch to
other sources of fuel.
Clean Water Act
The Clean Water Act of 1972 affects coal mining operations by imposing
restrictions on effluent discharge into water. Regular monitoring, reporting
requirements and performance standards are preconditions for the issuance and
renewal of permits governing the discharge of pollutants into water.
Resource Conservation and Recovery Act
RCRA imposes requirements for the treatment, storage and disposal of
hazardous wastes. Coal mining operations covered by the Surface Mining Control
and Reclamation Act permits are exempted from regulation under RCRA by statute.
We cannot, however, predict whether this exclusion will continue.
RCRA excludes certain large-volume wastes generated primarily from the
combustion of coal from being regulated as a hazardous waste pending a report to
Congress and a decision by the EPA either to regulate the coal combustion wastes
as a hazardous waste under RCRA or deem the regulation as unwarranted. The EPA
made its report to Congress in March 1999 and determined in May 2000 not to
regulate coal waste as a hazardous substance under RCRA. Any requirement to
regulate coal combustion waste as a hazardous waste could cause a switch to
other lower ash fuels and reduce the amount of coal used by electric generators.
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
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Superfund, joint and several liability may be imposed on waste generators, site
owners and operators and others regardless of fault.
Global Climate Change
The United States, Australia and over 160 other nations are signatories to
the 1992 Framework Convention on Climate Change, which is intended to limit
emissions of greenhouse gases, such as carbon dioxide. In December 1997, in
Kyoto, Japan, the signatories to the convention established a binding set of
emission targets for developed nations. Although the specific emission targets
vary from country to country, the United States would be required to reduce
emissions to 93% of 1990 levels over a five-year budget period from 2008 through
2012. Although the United States has not ratified the emission targets and no
comprehensive regulations focusing on greenhouse gas emissions are in place,
these restrictions, whether through ratification of the emission targets or
other efforts to stabilize or reduce greenhouse gas emissions, could adversely
affect the price and demand for coal. According to the Energy Information
Administration's Emissions of Greenhouse Gases in the United States 1999, coal
accounts for 30% of greenhouse gas emissions in the United States, and efforts
to control greenhouse gas emissions could result in reduced use of coal if
electric generators switch to lower carbon sources of fuel. In March 2001,
President Bush reiterated his opposition to the Kyoto Protocol and further
stated that he did not believe that the government should impose mandatory
carbon dioxide emission reductions on power plants.
PERMITTING
Mining companies must obtain numerous permits that impose strict
regulations on various environmental and safety matters in connection with coal
mining. These provisions include requirements for coal prospecting; mine plan
development; topsoil removal, storage and replacement; selective handling of
overburden materials; mine pit backfilling and grading; protection of the
hydrologic balance; subsidence control for underground mines; surface drainage
control; mine drainage and mine discharge control and treatment; and
revegetation.
We must obtain permits from applicable state regulatory authorities before
we begin to mine reserves. The mining permit application process is initiated by
collecting baseline data to adequately characterize the pre-mine environmental
condition of the permit area. This work includes surveys of cultural resources,
soils, vegetation, wildlife, assessment of surface and ground water hydrology,
climatology and wetlands. In conducting this work, we collect geologic data to
define and model the soil and rock structures and coal that we will mine. We
develop mine and reclamation plans by utilizing this geologic data and
incorporating elements of the environmental data. The mine and reclamation plan
incorporates the provisions of the Surface Mining Control and Reclamation Act,
the state programs and the complementary environmental programs that impact coal
mining. Also included in the permit application are documents defining ownership
and agreements pertaining to coal, minerals, oil and gas, water rights, rights
of way, and surface land and documents required of the Office of Surface
Mining's Applicant Violator System.
Once a permit application is prepared and submitted to the regulatory
agency, it goes through a completeness review, technical review and public
notice and comment period before it can be approved. Some Surface Mining Control
and Reclamation Act mine permits can take over a year to prepare, depending on
the size and complexity of the mine and often take six months to sometimes two
years to receive approval. Regulatory authorities have considerable discretion
in the timing of the permit issuance and the public has rights to comment on and
otherwise engage in the permitting process, including through intervention in
the courts.
We do not believe there are any substantial matters that pose a risk to
maintaining our existing mining permits or hinder our ability to acquire future
mining permits. It is our policy to ensure that our operations are in full
compliance with the requirements of the Surface Mining Control and Reclamation
Act and the state laws and regulations governing mine reclamation.
ADDITIONAL INFORMATION
We file annual, quarterly and current reports and other information with
the SEC. You may access and read our SEC filings through the SEC's Internet site
at www.sec.gov. This site contains reports and other information that we file
electronically with the SEC. You may also read and copy any document we file at
the SEC's public reference room located at 450 Fifth Street, N.W., Washington,
D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the
public reference room.
You may request copies of the filings, at no cost, by telephone at (314)
342-3400 or by mail at: Peabody Energy Corporation, 701 Market Street, Suite
700, St. Louis, Missouri 63101, attention: Public Relations.
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ITEM 2. PROPERTIES.
Coal Reserves
We had an estimated 9.3 billion tons of proven and probable coal reserves
as of March 1, 2001, of which approximately 41% is compliance coal and 59% is
non-compliance coal. We own approximately 45% of these reserves and lease the
remaining 55%. Compliance coal is defined by Phase II of the Clean Air Act as
coal having sulfur dioxide content of 1.2 pounds or less per million Btu.
Electricity generators are able to use coal that exceeds these specifications by
using emissions reduction technology, using emissions allowance credits or
blending higher sulfur coal with lower sulfur coal.
Below is a table summarizing the locations and reserves of our major
operating units.
PROVEN AND PROBABLE
RESERVES AS OF
MARCH 1, 2001(1)
-----------------------
OWNED LEASED TOTAL
TONS TONS TONS
LOCATIONS ----- ------ -----
OPERATING REGIONS --------- (Tons in millions)
-----------------
Powder River Basin Wyoming and Montana................................................... 190 3,147 3,337
Southwest Arizona, Colorado and New Mexico...................................... 672 583 1,255
Appalachia West Virginia......................................................... 310 413 723
Midwest Illinois, Indiana and Kentucky........................................ 3,030 1,001 4,031
----- ----- -----
Total...................................................................................... 4,202 5,144 9,346
===== ===== =====
--------------
(1) Reserves have been adjusted to take into account estimated losses involved
in producing a saleable product.
Proven and probable coal reserves are classified as follows:
Proven Reserves--Reserve estimates in this category have the
highest degree of geologic assurance. Proven coal lies within one-quarter
mile of a valid point of measurement or point of observation (such as
exploratory drill holes or previously mined areas) supporting such
measurements. The sites for thickness measurement are so closely spaced,
and the geologic character is so well defined, that the average thickness,
areal extent, size, shape and depth of coalbeds are well established.
Probable Reserves--Reserve estimates in this category have a moderate
degree of geologic assurance. There are no sample and measurement sites in
areas of indicated coal. However, a single measurement can be used to
classify coal lying beyond measured as probable. Probable coal lies more
than one-quarter mile, but less than three quarters of a mile from a point
of thickness measurement. Further exploration is necessary to place
probable coal into the proven category.
In areas where geologic conditions indicate potential inconsistencies
related to coal reserves, we perform additional drilling to ensure the
continuity and mineability of the coal reserves. Consequently, sampling in those
areas involves drill holes that are spaced closer together than those distances
cited above.
We prepare our reserve estimates based on geological data assembled and
analyzed by our staff, which includes various geologists and engineers. We
periodically update our reserve estimates to reflect production of coal from the
reserves and new drilling or other data received. Accordingly, reserve estimates
will change from time to time to reflect mining activities, analysis of new
engineering and geological data, changes in reserve holdings, modification of
mining methods and other factors. We maintain reserve information, including the
quantity and quality (where available) of reserves as well as production rates,
surface ownership, lease payments and other information relating to our coal
reserve and land holdings, through a computerized land management system that we
developed.
Our reserve estimates are predicated on information obtained from our
extensive drilling program, which totals nearly 500,000 individual drill holes.
We compile data from individual drill holes in a computerized drill-hole system
from which the depth, thickness and, where core drilling is used, the quality of
the coal are determined. The density of the drill pattern determines whether the
reserves will be classified as proven or probable. The drill hole data are then
input into our computerized land management system, which overlays the
geological data with data on ownership or control of the mineral and surface
interests to determine the extent of our reserves in a given area. In addition,
we periodically engage independent mining and geological consultants to review
estimates of our coal reserves. The most recent of these reviews, which was
completed in March 2001, included a review of the procedures used by us to
prepare our internal estimates, verification of the accuracy of selected
property reserve estimates and retabulation of reserve groups according to
standard classifications of reliability. This study confirmed that
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we controlled approximately 9.5 billion tons of proven and probable reserves as
of April 1, 2000. After adjusting for production through March 1, 2001, proven
and probable reserves totaled 9.3 billion tons.
We have numerous federal coal leases that are administered by the
Department of the Interior under the Federal Coal Leasing Amendments Act of
1976. These leases cover our principal reserves in Wyoming and other reserves in
Montana and Colorado. Each of these leases continues indefinitely, provided
there is diligent development of the property and continued operation of the
related mine or mines. The Bureau of Land Management has asserted the right to
adjust the terms and conditions of these leases, including rent and royalties,
after the first 20 years of their term and at 10-year intervals thereafter.
Annual rents under our federal coal leases are now set at $3.08 per acre.
Production royalties on federal leases are set by statute at 12.5% of the gross
proceeds of coal mined and sold for surface-mined coal and 8% for
underground-mined coal. The federal government limits by statute the amount of
federal land that may be leased by any company and its affiliates at any time to
75,000 acres in any one state and 150,000 acres nationwide. As of March 31,
2001, we leased or applied to lease 23,386 acres of federal land in Colorado,
11,252 acres in Montana, 30,167 acres in Wyoming for a total of 64,805
nationwide.
Similar provisions govern three coal leases with the Navajo and Hopi Indian
tribes. These leases cover coal contained in 65,000 acres of land in northern
Arizona lying within the boundaries of the Navajo Nation and Hopi Indian
reservations. We also lease coal-mining properties from various state
governments.
Private coal leases normally have terms of between ten and 20 years and
usually give us the right to renew the lease for a stated period or to maintain
the lease in force until the exhaustion of mineable and merchantable coal
contained on the relevant site. These private leases provide for royalties to be
paid to the lessor either as a fixed amount per ton or as a percentage of the
sales price. Many leases also require payment of a lease bonus or minimum
royalty, payable either at the time of execution of the lease or in periodic
installments.
The terms of our private leases are normally extended by active production
on or near the end of the lease term. Leases containing undeveloped reserves may
expire or these leases may be renewed periodically. With a portfolio of
approximately 9.3 billion tons, we believe that we have sufficient reserves to
replace capacity from depleting mines for the foreseeable future and that our
reserve base is one of our strengths. We believe that the current level of
production at our major mines is sustainable.
Consistent with industry practice, we conduct only limited investigation of
title to our coal properties prior to leasing. Title to lands and reserves of
the lessors or grantors and the boundaries of our leased properties are not
completely verified until we prepare to mine those reserves.
17
18
The following chart provides a summary, by mining complex, of production
for fiscal years 1999, 2000 and 2001, tonnage of coal reserves that is assigned
to our operating mines, our property interest in those reserves and other
characteristics of the facilities.
PRODUCTION AND ASSIGNED RESERVES(1)
(Tons in millions)
SULFUR CONTENT(2)
PRODUCTION ----------------------------------------------
---------------------------- >1.2 TO
FISCAL FISCAL FISCAL <1.2 POUNDS 2.5 POUNDS >2.5 POUNDS
SULFUR DIOXIDE SULFUR DIOXIDE SULFUR DIOXIDE
YEAR YEAR YEAR PER PER PER
MINING COMPLEX 1999 2000 2001 TYPE OF COAL MILLION BTU MILLION BTU MILLION BTU
-------------- ------ ------ ------ ------------ -------------- -------------- --------------
Northern Appalachia:
Federal No. 2................ 4.8 4.2 4.7 Steam -- -- 54.5
----- ----- ----- ------- ----- -----
Northern Appalachia.......... 4.8 4.2 4.7 -- -- 54.5
Southern Appalachia:
Big Mountain/White's Branch.. 1.9 2.1 2.0 Steam 22.4 9.1 --
Harris....................... 3.6 3.2 3.9 Steam/Metallurgical 22.1 1.7 --
Rocklick..................... 3.8 3.3 3.2 Steam/Metallurgical 19.3 8.4 --
Wells........................ 2.8 2.0 1.6 Steam/Metallurgical 16.9 5.8 --
----- ----- ----- ------- ----- -----
Southern Appalachia.......... 12.1 10.5 10.7 80.7 25.0 --
Midwest:
Camp(4)...................... 6.4 6.4 5.4 Steam -- -- 129.2
Hawthorn(5).................. 3.1 2.1 -- Steam N/A N/A N/A
Lynnville(6)................. 3.0 2.2 -- Steam N/A N/A N/A
Marissa(7)................... 4.2 2.3 -- Steam N/A N/A N/A
Midwest...................... 1.2 1.2 1.2 Steam -- -- 2.5
Patriot...................... 1.6 1.9 2.0 Steam -- -- 51.3
Black Beauty:
Air Quality No. 1.......... 1.7 1.8 1.7 Steam 58.3 -- --
Riola No. 1(8)............. -- 0.4 1.0 Steam -- -- 11.6
Cedar Creek(9)............. 0.3 -- -- Steam N/A N/A N/A
Sugar Ridge(10)............ -- -- 0.1 Steam -- 0.9 --
Francisco.................. 2.9 2.8 2.2 Steam -- -- 13.9
Eel(11).................... 0.2 -- -- Steam N/A N/A N/A
Columbia................... 1.0 0.7 0.8 Steam -- 0.2 --
Discovery(12).............. 0.6 0.6 0.3 Steam -- -- 2.3
Farmersburg................ 3.2 3.5 4.1 Steam -- 27.0 --
Birdwell/Miller Creek...... 1.6 1.4 0.9 Steam -- -- 2.9
Somerville Central(13)..... -- -- 2.0 Steam -- -- 17.8
Somerville North........... 1.9 2.0 2.8 Steam -- -- 5.8
Viking..................... 1.3 1.3 1.0 Steam -- -- 1.6
Sugar Camp Coal............ 3.6 5.6 5.0 Steam -- -- 17.5
West Fork(14).............. 0.5 0.5 0.2 Steam N/A N/A N/A
Lyons(15).................. 0.1 -- -- Steam N/A N/A N/A
Deanefield................. -- 0.4 0.8 Steam -- -- 3.3
----- ----- ----- ------- ----- -----
Midwest...................... 38.3 37.0 31.5 58.3 28.1 259.7
Powder River Basin:
Big Sky...................... 3.1 2.4 1.7 Steam -- 33.1 28.6
North Antelope/Rochelle...... 66.6 68.3 72.3 Steam 1,507.3 -- --
Caballo...................... 26.9 26.1 25.6 Steam 850.0 95.3 --
Rawhide(16).................. 3.3 -- -- Steam N/A N/A N/A
----- ----- ----- ------- ----- -----
Powder River Basin........... 99.9 96.9 99.6 2,357.3 128.4 28.6
Southwest:
Black Mesa................... 4.4 4.5 4.9 Steam 91.5 2.6 --
Kayenta...................... 6.9 7.6 8.5 Steam 253.4 80.4 --
Lee Ranch.................... 5.0 4.9 5.2 Steam -- 176.6 --
Seneca....................... 1.6 1.4 1.5 Steam 15.7 -- --
----- ----- ----- ------- ----- -----
Southwest.................... 17.8 18.5 20.1 360.6 259.6 --
----- ----- ----- ------- ----- -----
Total.......................... 173.0 167.1 166.6 2,856.9 441.1 342.8
===== ===== ===== ======= ===== =====
AS OF MARCH 1, 2001
AS ----------------------------------------------------------------
RECEIVED ASSIGNED
BTU PER PROVEN AND
MINING COMPLEX POUND(3) PROBABLE RESERVES OWNED LEASED SURFACE UNDERGROUND
-------------- -------- ----------------- ----- ------ ------- -----------
Northern Appalachia:
Federal No. 2................ 13,375 54.5 54.5 -- -- 54.5
------- ----- ------- ------- -----
Northern Appalachia.......... 54.5 54.5 -- -- 54.5
Southern Appalachia:
Big Mountain/White's Branch.. 12,319 31.5 -- 31.5 -- 31.5
Harris....................... 13,550 23.8 -- 23.8 -- 23.8
Rocklick..................... 12,900 27.7 -- 27.7 -- 27.7
Wells........................ 13,630 22.7 -- 22.7 -- 22.7
------- ----- ------- ------- -----
Southern Appalachia.......... 105.7 -- 105.7 -- 105.7
Midwest:
Camp(4)...................... 11,525 129.2 2.8 126.4 -- 129.2
Hawthorn(5).................. N/A N/A N/A N/A N/A N/A
Lynnville(6)................. N/A N/A N/A N/A N/A N/A
Marissa(7)................... N/A N/A N/A N/A N/A N/A
Midwest...................... 10,166 2.5 1.7 0.8 2.0 0.5
Patriot...................... 10,600 51.3 -- 51.3 3.2 48.1
Black Beauty:
Air Quality No. 1.......... 11,164 58.3 0.5 57.8 -- 58.3
Riola No. 1(8)............. 10,553 11.6 -- 11.6 -- 11.6
Cedar Creek(9)............. N/A N/A N/A N/A N/A N/A
Sugar Ridge(10)............ 11,616 0.9 -- 0.9 -- 0.9
Francisco.................. 11,513 13.9 3.2 10.7 13.9 --
Eel(11).................... N/A N/A N/A N/A N/A N/A
Columbia................... 11,519 0.2 -- 0.2 0.2 --
Discovery(12).............. 10,660 2.3 0.1 2.2 -- 2.3
Farmersburg................ 10,814 27.0 23.5 3.5 27.0 --
Birdwell/Miller Creek...... 11,591 2.9 -- 2.9 2.9 --
Somerville Central(13)..... 11,124 17.8 17.7 0.1 17.8 --
Somerville North........... 11,119 5.8 5.8 -- 5.8 --
Viking..................... 11,675 1.6 -- 1.6 1.6 --
Sugar Camp Coal............ 12,148 17.5 9.1 8.4 4.2 13.3
West Fork(14).............. N/A N/A N/A N/A N/A N/A
Lyons(15).................. N/A N/A N/A N/A N/A N/A
Deanefield................. 11,120 3.3 -- 3.3 3.3 --
------- ----- ------- ------- -----
Midwest...................... 346.1 64.4 281.7 81.9 264.2
Powder River Basin:
Big Sky...................... 8,800 61.7 -- 61.7 61.7 --
North Antelope/Rochelle...... 8,750 1,507.3 -- 1,507.3 1,507.3 --
Caballo...................... 8,500 945.3 -- 945.3 945.3 --
Rawhide(16).................. N/A N/A N/A N/A N/A N/A
------- ----- ------- ------- -----
Powder River Basin........... 2,514.3 -- 2,514.3 2,514.3 --
Southwest:
Black Mesa................... 10,671 94.1 -- 94.1 94.1 --
Kayenta...................... 10,717 333.8 -- 333.8 333.8 --
Lee Ranch.................... 9,200 176.6 174.9 1.7 176.6 --
Seneca....................... 10,408 15.7 1.3 14.4 15.7 --
------- ----- ------- ------- -----
Southwest.................... 620.2 176.2 444.0 620.2 --
------- ----- ------- ------- -----
Total.......................... 3,640.8 295.1 3,345.7 3,216.4 424.4
======= ===== ======= ======= =====
18
19
The following chart provides a summary of the amount of our proven and
probable coal reserves in each state, the predominant type of coal mined in the
applicable state, our property interest in the reserves and other
characteristics of the facilities.
ASSIGNED AND UNASSIGNED PROVEN AND PROBABLE COAL RESERVES(1)
AS OF MARCH 1, 2001
(Tons in millions)
SULFUR CONTENT(2)
-----------------------------------------------
<1.2 POUNDS >1.2 TO 2.5 POUNDS >2.5 POUNDS
TOTAL TONS PROVEN AND SULFUR DIOXIDE SULFUR DIOXIDE SULFUR DIOXIDE
-------------------- PROBABLE TYPE OF PER PER PER
LOCATION ASSIGNED UNASSIGNED RESERVES PROVEN PROBABLE COAL MILLION BTU MILLION BTU MILLION BTU
-------- -------- ---------- ---------- ------ -------- ------- -------------- -------------- --------------
Northern Appalachia:
West Virginia......... 54.5 -- 54.5 33.2 21.3 Steam -- -- 54.5
------- ------- ------- ------- ------- ------- ------- --------
Northern Appalachia... 54.5 -- 54.5 33.2 21.3 -- -- 54.5
Southern Appalachia:
Ohio.................. -- 78.1 78.1 55.1 23.0 Steam -- -- 78.1
Steam/
West Virginia......... 105.7 484.6 590.3 414.8 175.5 Metallurgical 311.8 249.6 28.9
------- ------- ------- ------- ------- ------- ------- --------
Southern Appalachia... 105.7 562.7 668.4 469.9 198.5 311.8 249.6 107.0
Midwest:
Illinois.............. -- 2,202.8 2,202.8 1,041.6 1,161.2 Steam 4.9 65.6 2,132.3
Indiana............... -- 333.7 333.7 213.2 120.5 Steam 0.1 3.7 329.9
Kentucky.............. 183.3 866.6 1,049.9 625.4 424.5 Steam 0.2 0.3 1,049.4
Black Beauty Coal
Company (Illinois,
Indiana, Kentucky).. 162.8 270.6 433.4 182.2 251.2 Steam 62.4 47.6 323.4
Missouri.............. -- 11.9 11.9 10.7 1.2 Steam -- -- 11.9
------- ------- ------- ------- ------- ------- ------- --------
Midwest............... 346.1 3,685.6 4,031.7 2,073.1 1,958.6 67.6 117.2 3,846.9
Powder River Basin:
Montana............... 61.8 301.4 363.2 334.9 28.3 Steam 43.7 179.0 140.5
Wyoming............... 2,452.5 521.7 2,974.1 2,837.5 136.6 Steam 2,792.5 173.8 7.8
------- ------- ------- ------- ------- ------- ------- --------
Powder River Basin.... 2,514.3 823.1 3,337.3 3,172.4 164.9 2,836.2 352.8 148.3
Southwest:
Arizona............... 427.9 -- 427.9 427.9 -- Steam 344.8 83.1 --
Colorado.............. 15.7 136.3 152.1 125.4 26.7 Steam 42.8 108.7 0.6
New Mexico............ 176.6 493.9 670.5 209.0 461.5 Steam 214.5 406.0 50.0
Utah.................. -- 3.6 3.6 -- 3.6 Steam 3.6 -- --
------- ------- ------- ------- ------- ------- ------- --------
Southwest............. 620.2 633.8 1,254.1 762.3 491.8 605.7 597.8 50.6
------- ------- ------- ------- ------- ------- ------- --------
Total Proven and
Probable................ 3,640.8 5,705.2 9,346.0 6,510.9 2,835.1 3,821.3 1,317.4 4,207.3
======= ======= ======= ======= ======= ======= ======= ========
AS-
RECEIVED RESERVE CONTROL MINING METHOD
BTU PER ------------------- ---------------------------
LOCATION POUND(17) OWNED LEASED SURFACE UNDERGROUND
-------- --------- ----- ------ ------- -----------
Northern Appalachia:
West Virginia......... 13,540 54.5 -- -- 54.5
------- ------- ------- -------
Northern Appalachia... 54.5 -- -- 54.5
Southern Appalachia:
Ohio.................. 11,160 78.1 -- 0.1 78.0
West Virginia........... 12,170 177.3 413.0 40.9 549.4
------- ------- ------- -------
Southern Appalachia... 255.4 413.0 41.0 627.4
Midwest:
Illinois.............. 10,520 2,171.8 31.0 53.3 2,149.5
Indiana............... 10,380 274.7 59.0 101.6 232.1
Kentucky.............. 10,990 396.6 653.3 113.0 936.9
Black Beauty Coal
Company (Illinois,
Indiana, Kentucky).. 11,190 175.3 258.1 112.1 321.3
Missouri.............. 10,141 11.8 0.1 11.9 --
------- ------- ------- -------
Midwest............... 3,030.2 1,001.5 391.9 3,639.8
Powder River Basin:
Montana............... 8,710 189.1 174.1 363.2 --
Wyoming............... 8,660 1.0 2,973.1 2,974.1 --
------- ------- ------- -------
Powder River Basin.... 190.1 3,147.2 3,337.3 --
Southwest:
Arizona............... 10,510 -- 427.9 427.9 --
Colorado.............. 10,430 3.6 148.5 17.3 134.8
New Mexico............ 9,510 664.4 6.1 670.5 --
Utah.................. 10,430 3.6 -- -- 3.6
------- ------- ------- -------
Southwest............. 671.6 582.5 1,115.7 138.4
------- ------- ------- -------
Total Proven and
Probable................ 4,201.8 5,144.2 4,885.9 4,460.1
======= ======= ======= =======
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20
--------------
(1) Assigned reserves represent recoverable coal reserves that we have
committed to mine at locations operating as of March 1, 2001. Unassigned
reserves represent coal at suspended locations and coal that has not been
committed, and that would require new mine development, mining equipment
or plant facilities before operations could begin on the property.
(2) Compliance coal is defined by Phase II of the Clean Air Act as coal
having sulfur dioxide content of 1.2 pounds or less per million Btu.
Non-compliance coal is defined as coal having sulfur dioxide content in
excess of this standard. Electricity generators are able to use coal that
exceeds these specifications by using emissions reduction technology,
using emissions allowance credits or blending higher sulfur coal with
lower sulfur coal.
(3) As-received Btu per pound includes the weight of moisture in the coal on
an as-sold basis.
(4) The Camp No. 1 mine at the Camp operating unit was closed in October 2000.
(5) Production at the Hawthorn mine has been suspended since December 1999.
(6) Production at the Lynnville mine has been suspended since December 1999.
(7) The Marissa mine was closed in October 1999.
(8) The Riola No. 1 mine was acquired in October 1999.
(9) The Cedar Creek mine was closed in July 1998.
(10) The Sugar Ridge mine opened in December 2000.
(11) The Eel mine was closed in July 1998.
(12) The Discovery mine was temporarily idled from April 2000 to July 2000.
(13) The Somerville Central mine opened in March 2000.
(14) The West Fork mine closed in August 2000.
(15) The Lyons mine closed in September 1998.
(16) The Rawhide mine operated at reduced production during fiscal year 1999
and suspended production in March 1999.
(17) As-received Btu per pound includes the weight of moisture in the coal on
an as sold basis. The following table reflects the average moisture
content used in the determination of as-received Btu for the region:
Northern Appalachia...................................... 6.0%
Southern Appalachia...................................... 7.0%
Midwest:
Illinois............................................ 14.0%
Indiana............................................. 15.0%
Kentucky............................................ 12.5%
Black Beauty Coal Company........................... 14.5%
Missouri............................................ 12.0%
Powder River Basin:
Montana............................................. 26.5%
Wyoming............................................. 27.5%
Southwest:
Arizona............................................. 13.0%
Colorado............................................ 14.0%
New Mexico.......................................... 15.5%
Utah................................................ 15.5%
20
21
Resource Development
We hold approximately 9.3 billion tons of proven and probable coal
reserves. Our Resource Development group constantly reviews this reserve base
for opportunities to generate revenues through the sale of non-strategic coal
reserves and surface land. In addition, we generate revenue through royalties
from coal reserves leased to third parties and farm income from surface land
under third party contracts. The Resource Development group is also actively
pursuing opportunities in the area of coalbed methane extraction in the United
States through a new subsidiary, Peabody Natural Gas, LLC. In January 2001, we
purchased the coalbed methane assets of JN Exploration & Production Limited
Partnership for approximately $10 million.
ITEM 3. LEGAL PROCEEDINGS.
From time to time, we are involved in legal proceedings arising in the
ordinary course of business. We believe we have recorded adequate reserves for
these liabilities and that there is no individual case pending that is likely to
have a material adverse effect on our financial condition or results of
operations. We discuss our significant legal proceedings below.
Navajo Nation
On June 18, 1999, the Navajo Nation served our subsidiaries, Peabody
Holding Company, Inc., Peabody Coal Company and Peabody Western Coal Company,
with a complaint that had been filed in the U.S. District Court for the
District of Columbia. Other defendants in the litigation are two customers, one
current employee and one former employee. The Navajo Nation has alleged 16
claims, including Civil Racketeer Influenced and Corrupt Organizations Act, or
RICO, violations and fraud and tortious interference with contractual
relationships. The complaint alleges that the defendants jointly participated in
unlawful activity to obtain favorable coal lease amendments. Plaintiff also
alleges that defendants interfered with the fiduciary relationship between the
United States and the Navajo Nation. The plaintiff is seeking various remedies
including actual damages of at least $600 million, which could be trebled under
the RICO counts, punitive damages of at least $1 billion, a determination that
Peabody Western Coal Company's two coal leases for the Kayenta and Black Mesa
mines have terminated due to our breach of these leases and a reformation of the
two coal leases to adjust the royalty rate to 20%. All defendants have filed
motions to dismiss the complaint. On March 15, 2001, the court denied the
Peabody defendants' motions to dismiss.
In March 2000, the Hopi Tribe filed a motion to intervene in this lawsuit.
The Hopi Tribe has alleged seven claims, including fraud. The Hopi Tribe is
seeking various remedies, including unspecified actual and punitive damages,
reformation of its coal lease and a termination of the coal lease. On March 15,
2001, the court granted the Hopi Tribe's motion. On April 17, 2001, we filed a
motion to dismiss the Hopi complaint.
While the outcome of litigation is subject to uncertainties, based on our
preliminary evaluation of the issues and the potential impact on us, we believe
this matter will be resolved without a material adverse effect on our financial
condition or results of operations.
Salt River Project Agricultural Improvement and Power District--Price Review
In May 1997, Salt River Project Agricultural Improvement and Power
District, or Salt River, acting for all owners of the Navajo Generating Station,
exercised their contractual option to review certain cumulative cost changes
during a five-year period from 1992 to 1996. Peabody Western sells approximately
7 to 8 million tons of coal per year to the owners of the Navajo Generation
Station under a long-term contract. In July 1999, Salt River notified Peabody
Western that it believed the owners were entitled to a price decrease of $1.92
per ton as a result of the review. Salt River also claimed entitlement to a
retroactive price adjustment to January 1997 and that an overbilling of $50.5
million had occurred during the same five-year period. In October 1999, Peabody
Western notified Salt River that it believed it was entitled to a $2.00 per ton
price increase as a result of the review. The parties were unable to settle the
dispute and Peabody Western filed a demand for arbitration in September 2000.
The arbitration panel has been selected and the hearing is scheduled to start on
October 29, 2001.
On February 12, 2001 in a related action, Salt River, again acting for all
owners of the Navajo Generating Station, filed a lawsuit against Peabody Western
in the Superior Court in Maricopa County in Arizona. This lawsuit seeks to
compel arbitration of issues that Peabody Western does not believe are subject
to arbitration, namely, (1) the effective date of any price change resulting
from the resolution of the price review arbitration discussed above and (2) the
validity of Salt River's $50.5 million claim for alleged overcharges by Peabody
Western for the period from 1992 through 1996 (the five-year period that was the
subject of the price review). If the court declines to compel arbitration of
these issues, the lawsuit alternatively requests that the court find in favor of
Salt River on these issues. We have removed this matter to the U.S. District
Court for the District of Arizona.
21
22
While the outcome of arbitration and litigation is subject to
uncertainties, based on our preliminary evaluation of the issues and the
potential impact on us, we believe that the matter will be resolved without a
material adverse effect on our financial condition or results of operations.
Salt River Project Agricultural Improvement and Power District--Mine Closing and
Retiree Health Care
Salt River and the other owners of the Navajo Generating Station filed a
lawsuit on September 27, 1996 in the Superior Court of Maricopa County in
Arizona seeking a declaratory judgment that certain costs relating to final
reclamation, environmental monitoring work and mine decommissioning and costs
primarily relating to retiree health care benefits are not recoverable by our
subsidiary, Peabody Western Coal Company, under the terms of a coal supply
agreement dated February 18, 1977. The contract expires in 2011.
Peabody Western filed a motion to compel arbitration of these claims, which
was granted in part by the trial court. Specifically, the trial court ruled that
the mine decommissioning costs were subject to arbitration but that the retiree
health care costs were not subject to arbitration. Peabody Western appealed and
the Arizona Court of Appeals affirmed the trial court's order. Peabody Western
filed a petition for review with the Arizona Supreme Court. That petition was
denied on September 24, 1998. As a result, Peabody Western, Salt River and the
other owners of the Navajo Generating Station will arbitrate the mine
decommissioning costs issue and will litigate the retiree health care costs
issue.
While the outcome of litigation and arbitration is subject to
uncertainties, based on our preliminary evaluation of the issues and the
potential impact on us, and based on outcomes in similar proceedings, we believe
that the matter will be resolved without a material adverse effect on our
financial condition or results of operations.
Southern California Edison Company
In response to a demand for arbitration by one of our subsidiaries, Peabody
Western, Southern California Edison and the other owners of the Mohave
Generating Station filed a lawsuit on June 20, 1996 in the Superior Court of
Maricopa County, Arizona. The lawsuit sought a declaratory judgment that mine
decommissioning costs and retiree health care costs are not recoverable by
Peabody Western under the terms of a coal supply agreement dated May 26, 1976.
The contract expires in 2005.
Peabody Western filed a motion to compel arbitration which was granted by
the trial court. Southern California Edison appealed this order to the Arizona
Court of Appeals, which denied its appeal. Southern California Edison then
appealed the order to the Arizona Supreme Court which remanded the case to the
Arizona Court of Appeals and ordered the appellate court to determine whether
the trial court was correct in determining that Peabody Western's claims are
arbitrable. The Arizona Court of Appeals ruled that neither mine decommissioning
costs nor retiree health care costs are to be arbitrated and that both issues
should be resolved in litigation. The matter has been remanded back to the
Superior Court of Maricopa County, Arizona, where a trial has been set for
September 11, 2001. Peabody Western answered the complaint and asserted
counterclaims. The court then permitted Southern California Edison to amend its
complaint to add a claim of overcharges of at least $19.2 million by Peabody
Western. The court also ruled that the claim for the overcharges and for damages
resulting from the September 2001 trial would be tried separately, following the
resolution of the September 2001 trial.
While the outcome of litigation is subject to uncertainties, based on our
preliminary evaluation of the issues and the potential impact on us, and based
on outcomes in similar proceedings, we believe that the matter will be resolved
without a material adverse effect on our financial condition or results of
operations. We had a receivable on our balance sheet at March 31, 2001 for the
mine closing costs associated with the Salt River and Southern California Edison
matters of $81.5 million.
Social Security Administration
In 1999, Eastern Associated Coal Corp. and Peabody Coal Company filed a
lawsuit in the U.S. District Court for the Western District of Kentucky against
the Social Security Administration asserting that the Social Security
Administration had improperly assigned, under the Coal Act, certain
beneficiaries to us. Subsequently, Peabody Coal and Eastern Associated moved for
summary judgment on this claim. Summary judgment was granted and in 2000, the
Social Security Administration filed an appeal of the district court's decision
with the U.S. Court of Appeals for the Sixth Circuit. On June 21, 2001, the
Sixth Circuit Court rejected the Social Security Administration's appeal.
Accordingly, we believe that the matter will be resolved without a material
adverse effect on our financial condition or results of operations.
22
23
Environmental
Federal and State Superfund Statutes. Superfund and similar state laws
create liability for investigation and remediation in response to releases of
hazardous substances in the environment and for damages to natural resources.
Under that legislation and many state Superfund statutes, joint and several
liability may be imposed on waste generators, site owners and operators and
others regardless of fault.
Our subsidiary, Gold Fields Mining Corporation, its predecessors and its
former parent company are or may become parties to environmental proceedings
that have commenced or may commence in the United States in relation to certain
sites previously owned or operated by those entities or companies associated
with them. We have agreed to indemnify Gold Fields' former parent company for
any environmental claims resulting from any activities, operations or conditions
that occurred prior to the sale of Gold Fields to us. Gold Fields is currently
involved in environmental investigation or remediation at nine sites and is a
defendant in litigation with private parties involving two additional sites.
These ten sites were formerly owned or operated by Gold Fields. The
Environmental Protection Agency has placed four of these sites on the National
Priorities List, promulgated pursuant to Superfund, and one of the sites is on a
similar state priority list. There are a number of additional sites in the
United States that were previously owned or operated by such companies that
could give rise to environmental proceedings in which Gold Fields could incur
liabilities.
Where the sites were identified, independent environmental consultants were
employed in 1997 in order to assess the estimated total amount of the liability
per site and the proportion of those liabilities that Gold Fields is likely to
bear. The available information on which to base this review was very limited
since all of the sites except for two sites (on which no remediation is
currently taking place) are no longer owned by Gold Fields. Independent
environmental consultants conducted another assessment in 2000. We have accrued
liabilities of $48.0 million as of March 31, 2001 for the environmental
liabilities described above relating to Gold Fields that are included as part of
the overall provision for reclamation and environmental liabilities in our
consolidated financial statements. Significant uncertainty exists as to whether
these claims will be pursued against Gold Fields in all cases, and where they
are pursued, the amount of the eventual costs and liabilities, which could be
greater or less than this provision. We believe that the remaining amount of the
provision is adequate to cover these environmental liabilities.
Although waste substances generated by coal mining and processing are
generally not regarded as hazardous substances for the purposes of Superfund and
similar legislation, some products used by coal companies in operations, such as
chemicals, and the disposal of these products are governed by the statute. Thus,
coal mines currently or previously owned or operated by us, and sites to which
we have sent waste materials, may be subject to liability under Superfund and
similar state laws.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
No matters were submitted to a vote of security holders during the fourth
quarter of fiscal year 2001.
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PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS.
In May 2001 we completed an initial public offering of our common stock and
sold 17.25 million shares to the public at an offering price of $28 per share.
Our net proceeds from the offering totaled $451.8 million. Our Common Stock is
listed on the New York Stock Exchange, under the symbol "BTU."
After completion of the offering, our authorized capital stock consisted of
(1) 150.0 million shares of common stock, par value $0.01 per share, of which
51.9 million shares of common stock are issued and outstanding, (2) 10.0 million
shares of preferred stock, par value $.01 per share, of which no shares are
issued and outstanding and (3) 40.0 million shares of common stock, par value
$.01 per share, of which no shares are issued and outstanding. As of May 31,
2001, there were approximately 8,800 holders of our common stock.
DIVIDEND POLICY
We paid no dividends in fiscal years 2000 or 2001. We currently intend to
declare and pay quarterly dividends of $0.10 per share in fiscal year 2002. The
declaration and payment of dividends and the amount of dividends will depend on
our results of operations, financial condition, cash requirements, future
prospects, any limitations imposed by our debt instruments and other factors
deemed relevant by our board of directors. Our Senior Credit Facility, as
amended, allows us to pay dividends of $25.0 million in fiscal year 2002 and
annual dividends in subsequent fiscal years equal to the greater of $25.0
million or 10% of consolidated EBITDA as defined in the facility. The indentures
governing our Senior Notes and Senior Subordinated Notes permit us to pay annual
dividends equal to 6% of our net proceeds from the offering, plus additional
amounts based on financial tests, although the actual amount of any dividends
will be determined by our board of directors.
RECENT SALES OF UNREGISTERED SECURITIES
During the fiscal year ended March 31, 2001, we sold shares of and issued
options for common stock and preferred stock in the amounts, at the times, and
for the aggregate amounts of consideration listed below without registration
under the Securities Act of 1933. Exemption from registration under the
Securities Act for each of the following sales is claimed under Section 4(2) of
the Securities Act because each of the transactions were by the issuer and did
not involve a public offering:
On July 1, 2000, we issued 42,087 shares of common stock to three
executives in consideration for their services.(2) Additionally, we issued
398,929 options to purchase common stock at an exercise price of $14.29(1) per
share to our executives and other employees.
On October 1, 2000, we issued 49,350 shares of common stock at an exercise
price of $14.29(1) per share to our executives.
On December 29, 2000 we issued 83,255 shares of common stock to nine
executives in consideration for their services in exchange for other shares
previously issued to them.
On January 1, 2001, we issued 945,263 options to purchase common stock at
an exercise price of $14.29(1) per share to executives and to other employees.
On February 1, 2001, we issued 205,304 shares of common stock for an
aggregate consideration of $1,096,912 to 20 of our executives.
On February 12, 2001, we issued 63,000 options to purchase common stock at
an exercise price of $14.29(1) per share to one of our executives.
Notes: (1) The exercise price of $14.29 per share reflects the 1.4-for-one
stock split we effected on May 17, 2001.
(2) These shares had been acquired by us from terminated employees.
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USE OF PROCEEDS
In connection with our initial public offering, the Securities and Exchange
Commission declared our Registration Statement on Form S-1 (File No. 333-55412)
relating to our common stock, $0.01 par value per share, effective on May 21,
2001. Lehman Brothers, Bear, Stearns & Co. Inc., Merrill Lynch & Co., Morgan
Stanley Dean Witter, UBS Warburg and A.G. Edwards & Sons, Inc. acted as
representatives of the underwriters for our initial public offering. We
completed the sale of all 17,250,000 shares of common stock registered under the
offering on May 22, 2001 and raised net proceeds of $451.8 million after
deducting total expenses of $31.2 million, comprised of the underwriters'
discounts and commissions of $27.2 million and other fees and expenses of $4.0
million. We did not make any direct or indirect payments to any of our
directors, officers or their associates under the offering; however, usual and
customary underwriting discounts and commissions were paid to Lehman Brothers
Inc. and Lehman Brothers International (Europe), each an affiliate of Lehman
Brothers Merchant Banking which beneficially owns 57% of our common stock.
We used the net proceeds from the offering to repay the remaining tranche B
term loan outstanding under the Senior Credit Facility of $125.0 million and
used $100.0 million to repay borrowings under our revolving credit facility that
were used to repay a portion of our 5% subordinated note. We also used $173.0
million of net proceeds to repurchase $80.0 million in principal amount of our
Senior Notes and $80.0 million in principal amount of our Senior Subordinated
Notes pursuant to a tender offer. In addition, we used $3.1 million and $12.7
million of proceeds to repurchase $2.9 million in principal amount of our Senior
Notes and $11.7 million in principal amount of our Senior Subordinated Notes,
respectively, in a private transaction. The remaining net proceeds of $38.0
million will be used for the repayment of debt and/or for general corporate
purposes. Except as described above, none of the net proceeds from our initial
public offering was used to make direct or indirect payments to (1) any of our
directors, officers or their associates, (2) any person owning 10% or more of
our equity securities, (3) any of our affiliates or (4) any others.
ITEM 6. SELECTED FINANCIAL DATA.
The following table presents selected financial and other data about us and
our predecessor. We purchased our operating subsidiaries on May 19, 1998, and
prior to that date we had no substantial operations. The period ended March 31,
1999 is thus a full fiscal year, but includes results of operations only from
May 20, 1998. For periods prior to May 19, 1998, the results of operations are
for the operating subsidiaries acquired, which we refer to as our "predecessor
company" and which we include for comparative purposes.
In early 1999, we increased our equity interest in Black Beauty Coal
Company from 43.3% to 81.7%. Our results of operations include the consolidated
results of Black Beauty, effective January 1, 1999. Prior to that date, we
accounted for our investment in Black Beauty under the equity method, under
which we reflected our share of Black Beauty's results of operations as a
component of "Other revenues" in the statements of operations, and our interest
in Black Beauty's net assets within "Investments and other assets" in the
balance sheets.
In anticipation of the sale of Citizens Power, which occurred in August
2000, we classified Citizens Power as a discontinued operation as of March 31,
2000, and recorded an estimated loss on the sale of $78.3 million, net of income
taxes. We have adjusted our results of operations to reflect the classification
of Citizens Power as a discontinued operation for all periods presented.
We have derived the selected historical financial data for our predecessor
for the year ended and as of September 30, 1996, the six months ended and as of
March 31, 1997, the year ended and as of March 31, 1998 and the period from
April 1, 1998 to May 19, 1998 and as of May 19, 1998, and the selected
historical financial data for our company for the period from May 20, 1998 to
March 31, 1999 and as of March 31, 1999 and the years ended and as of March 31,
2000 and 2001 from our predecessor company's and our audited financial
statements. You should read the following table in conjunction with the
financial statements, the related notes to those financial statements, and
"Management's Discussion and Analysis of Financial Condition and Results of
Operations."
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(Dollars in thousands, except per share data)
YEAR YEAR MAY 20,
ENDED ENDED TOTAL 1998 TO
MARCH 31, MARCH 31, FISCAL YEAR MARCH 31,
2001(1) 2000(2) 1999(3) 1999
----------- ----------- ------------ -----------
RESULTS OF OPERATIONS DATA:
Revenues:
Sales...................................................... $ 2,579,104 $ 2,610,991 $ 2,249,887 $ 1,970,957
Other revenues............................................. 90,588 99,509 97,603 85,875
----------- ----------- ----------- -----------
Total revenues......................................... 2,669,692 2,710,500 2,347,490 2,056,832
Costs and Expenses:
Operating costs and expenses............................... 2,165,090 2,178,664 1,887,846 1,643,718
Depreciation, depletion and amortization................... 240,968 249,782 204,698 179,182
Selling and administrative expenses........................ 99,267 95,256 88,905 76,888
Impairment of long-lived assets(4)......................... -- -- -- --
Gain on sale of Australian operations...................... (171,735) -- -- --
Net gain on property and equipment disposals............... (5,737) (6,439) (328) --
----------- ----------- ----------- -----------
Operating profit (loss)........................................ 341,839 193,237 166,369 157,044
Interest expense........................................... 197,686 205,056 180,327 176,105
Interest income............................................ (8,741) (4,421) (20,194) (18,527)
----------- ----------- ----------- -----------
Income (loss) before income taxes and minority interests....... 152,894 (7,398) 6,236 (534)
Income tax provision (benefit)............................. 42,690 (141,522) 7,542 3,012
Minority interests......................................... 7,524 15,554 1,887 1,887
----------- ----------- ----------- -----------
Income (loss) from continuing operations....................... 102,680 118,570 (3,193) (5,433)
Income (loss) from discontinued operations................. 12,925 (90,360) 4,678 6,442
----------- ----------- ----------- -----------
Income (loss) before extraordinary item........................ 115,605 28,210 1,485 1,009
Extraordinary loss from early extinguishment of debt....... (8,545) -- -- --
----------- ----------- ----------- -----------
Net income (loss).............................................. $ 107,060 $ 28,210 $ 1,485 $ 1,009
=========== =========== =========== ===========
Basic and diluted earnings (loss) per Class A/B share from
continuing operations.......................................... $ 2.97 $ 3.43 $ (0.16)
Weighted average shares used in calculating basic and diluted
earnings (loss) per Class A/B share............................ 27,524,626 27,586,370 26,823,383
OTHER DATA:
Tons sold (in millions)........................................ 192.4 190.3 176.0 154.3
Adjusted EBITDA(5)............................................. $ 582,807 $ 443,019 $ 371,067 $ 336,226
Net cash provided by (used in):
Operating activities....................................... 151,980 262,911 253,865 282,022
Investing activities....................................... 388,462 (185,384) (2,270,886) (2,249,336)
Financing activities....................................... (543,337) (205,181) 2,184,818 2,161,281
Depreciation, depletion and amortization....................... 240,968 249,782 204,698 179,182
Capital expenditures........................................... 187,060 178,754 195,394 174,520
BALANCE SHEET DATA (AT PERIOD END):
Total assets................................................... $ 5,209,487 $ 5,826,849 $ 7,023,931 $ 7,023,931
Total debt..................................................... 1,405,621 2,076,166 2,542,379 2,542,379
Total stockholders' equity/invested capital.................... 631,238 508,426 495,230 495,230
PREDECESSOR COMPANY
-----------------------------------------------------------
SIX
APRIL 1, YEAR MONTHS YEAR
1998 TO ENDED ENDED ENDED
MAY 19, MARCH 31, MARCH 31, SEPTEMBER 30,
1998 1998 1997 1996
----------- ----------- ------------ ------------
RESULTS OF OPERATIONS DATA:
Revenues:
Sales...................................................... $ 278,930 $ 2,048,694 $ 1,000,419 $ 2,075,142
Other revenues............................................. 11,728 169,328 63,674 118,444
----------- ----------- ----------- -----------
Total revenues......................................... 290,658 2,218,022 1,064,093 2,193,586
Costs and Expenses:
Operating costs and expenses............................... 244,128 1,695,216 822,938 1,693,543
Depreciation, depletion and amortization................... 25,516 200,169 101,730 197,853
Selling and administrative expenses........................ 12,017 83,640 41,421 75,699
Impairment of long-lived assets(4)......................... -- -- -- 890,829
Gain on sale of Australian operations...................... -- -- -- --
Net gain on property and equipment disposals............... (328) (21,815) (4,091) (13,042)
----------- ----------- ----------- -----------
Operating profit (loss)........................................ 9,325 260,812 102,095 (651,296)
Interest expense........................................... 4,222 33,410 24,700 62,526
Interest income............................................ (1,667) (14,543) (8,590) (11,355)
----------- ----------- ----------- -----------
Income (loss) before income taxes and minority interests....... 6,770 241,945 85,985 (702,467)
Income tax provision (benefit)............................. 4,530 83,050 27,553 (256,185)
Minority interests......................................... -- -- -- --
----------- ----------- ----------- -----------
Income (loss) from continuing operations....................... 2,240 158,895 58,432 (446,282)
Income (loss) from discontinued operations................. (1,764) 1,441 -- --
----------- ----------- ----------- -----------
Income (loss) before extraordinary item........................ 476 160,336 58,432 (446,282)
Extraordinary loss from early extinguishment of debt....... -- -- -- --
----------- ----------- ----------- -----------
Net income (loss).............................................. $ 476 $ 160,336 $ 58,432 $ (446,282)
=========== =========== =========== ===========
Basic and diluted earnings (loss) per Class A/B share from
continuing operations..........................................
Weighted average shares used in calculating basic and diluted
earnings (loss) per Class A/B share............................
OTHER DATA:
Tons sold (in millions)........................................ 21.7 167.5 81.4 163.0
Adjusted EBITDA(5)............................................. $ 34,841 $ 460,981 $ 203,825 $ (453,443)
Net cash provided by (used in):
Operating activities....................................... (28,157) 187,852 62,829 211,535
Investing activities....................................... (21,550) (136,033) (56,170) (105,640)
Financing activities....................................... 23,537 (235,389) 94,178 15,987
Depreciation, depletion and amortization....................... 25,516 200,169 101,730 197,853
Capital expenditures........................................... 20,874 165,514 76,460 152,106
BALANCE SHEET DATA (AT PERIOD END):
Total assets................................................... $ 6,406,587 $ 6,343,009 $ 5,025,812 $ 4,916,693
Total debt..................................................... 633,562 602,276 321,723 456,867
Total stockholders' equity/invested capital.................... 1,497,374 1,687,842 1,676,786 1,383,655
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--------------
(1) Results of operations for the year ended March 31, 2001 included a $171.7
million pretax gain on the sale of our Australian operations.
(2) Results of operations for the year ended March 31, 2000 included a $144.0
million income tax benefit associated with an increase in the tax basis of
a subsidiary's assets due to a change in federal income tax regulations.
(3) For comparative purposes, we derived the "Total Fiscal Year 1999" column by
adding the period from May 20, 1998 to March 31, 1999 with our predecessor
company results for the period from April 1, 1998 to May 19, 1998. The
effects of purchase accounting have not been reflected in the results of
our predecessor company.
(4) Results of operations for the year ended September 30, 1996 included a
one-time, non-cash charge of $890.8 million made pursuant to Statement of
Financial Accounting Standards No. 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets to be Disposed of."
(5) Adjusted EBITDA is defined as income from continuing operations before
deducting net interest expense, income taxes, minority interests and
depreciation, depletion and amortization. Adjusted EBITDA is not a
substitute for operating income, net income and cash flow from operating
activities as determined in accordance with generally accepted accounting
principles as a measure of profitability or liquidity. Adjusted EBITDA is
presented as additional information because management believes it is a
useful indicator of our ability to meet debt service and capital
expenditure requirements. Because Adjusted EBITDA is not calculated
identically by all companies, our calculation may not be comparable to
similarly titled measures of other companies.
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
FACTORS AFFECTING COMPARABILITY
Sale of Australian Operations
In December 2000, we signed a share purchase agreement for the transfer of
the stock in two U.K. holding companies which, in turn, owned our Australian
subsidiaries, to a subsidiary of Rio Tinto Limited. Our Australian operations
consisted of interests in six coal mines, as well as mining services in
Brisbane, Australia. The sale price was $446.8 million in cash, plus the
assumption of all liabilities including $119.4 million of debt. The sale closed
on January 29, 2001.
Discontinued Operations
In August 2000, we sold Citizens Power, our subsidiary that marketed and
traded electric power and energy-related commodity risk management products, to
Edison Mission Energy. We classified Citizens Power as a discontinued operation
as of March 31, 2000, and recorded an estimated loss on the sale of $78.3
million, net of income taxes. We have changed the presentation of our historical
results of operations and cash flows to reflect Citizens Power as a discontinued
operation for all periods presented. The fair value of the net assets of
Citizens Power is classified as a single line in the balance sheet entitled "Net
assets of discontinued operations" in fiscal year 2000 only.
Fiscal Year 2000 vs. Fiscal Year 1999
Effective January 1, 2000, our 81.7%-owned subsidiary, Black Beauty,
invested $6.6 million to obtain control of three of its midwestern coal mining
affiliates: Sugar Camp Coal, LLC, Arclar Coal Company, LLC and United Minerals
Company, LLC. Prior to fiscal year 2000, interests in these affiliates were
accounted for under the equity method and effective January 1, 2000, we obtained
decision-making control and began accounting for our 75% interest in the
affiliates on a consolidated basis. We have elected to consolidate these
affiliates as part of Black Beauty's results of operations effective April 1,
1999.
Fiscal year 2000 results also include the consolidated results of
operations for Black Beauty for 12 months compared to only three months in
fiscal year 1999. We increased our ownership interest in Black Beauty from 43.3%
to 81.7% effective January 1, 1999. We accounted for our interest in Black
Beauty under the equity method from April 1 to December 31, 1998. As a result,
prior to January 1, 1999, our share of Black Beauty's results of operations was
included as a component of "Other revenues" in the statements of operations, and
our interest in Black Beauty's net assets was included within "Investments and
other assets" in the balance sheets.
The results of operations and cash flows for the period ended March 31,
1999 reflect the combination of our results from April 1, 1998 to March 31, 1999
(we acquired our predecessor company effective May 20, 1998 and prior to that
date had no prior operations) and the results of the predecessor company for
April 1, 1998 to May 19, 1998. In addition, the results of operations and cash
flows for the period ended March 31, 1999 may not be directly comparable to
fiscal year 2000 as a result of the effects of restatement of assets and
liabilities to their estimated fair market value in accordance with the
application of purchase accounting under Accounting Principles Board Opinion No.
16.
FISCAL YEAR ENDED MARCH 31, 2001 COMPARED TO FISCAL YEAR ENDED MARCH 31, 2000
Sales. Sales decreased $31.9 million, or 1.2%, to $2,579.1 million for the
fiscal year 2001. Sales volume increased 2.1 million tons, or 1.1%, to 192.4
million tons in fiscal year 2001. The majority of the decline was the result of
$24.6 million of lower sales in Australia, due to the sale of our Australian
operations in January 2001. During the first nine months of fiscal year 2001,
average prices were 2.7% lower than the prior year's first nine months,
primarily due to a change in sales mix as higher-priced Midwest region volume
decreased in fiscal year 2001. However, this decrease was somewhat mitigated by
higher coal prices in the fourth quarter in nearly all operating regions, which
reduced the full year decline in average prices to only 1.0% compared to the
prior year. Sales from our U.S. operations decreased $7.3 million in fiscal year
2001, due to lower volumes in the Midwest region offset partially by slightly
higher volume in Appalachia, the Southwest region and at Black Beauty, and
improved pricing and volume in the Powder River Basin.
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Sales in the Powder River region increased $44.9 million in fiscal year
2001, due to improved pricing and increased volume as a result of strong demand
for Powder River Basin coal. Sales in Appalachia improved by $42.3 million due
to higher volume from improved performance at our longwall operations in that
region. Black Beauty's sales increased $23.6 million due to the higher volumes
on contracts transitioned from our other mines, while sales in the Southwest
region improved $4.9 million due to slightly higher sales volume. Sales from
broker and trading activities increased $41.4 million, reflecting an increase in
volume over fiscal year 2000. These sales increases were more than offset by the
sales decrease in the Midwest region of $164.5 million from the closure and
suspension of three mines during fiscal year 2000 and the closure of another
mine early in the third quarter of fiscal year 2001.
Other Revenues. Other revenues decreased $8.9 million compared to the prior
year, to $90.6 million. Lower contract restructuring revenues and coal royalty
income in fiscal year 2001 were only partially offset by an increase in revenues
from engineering services for underground mining projects in Australia. Our
contract restructuring revenues typically arise from the negotiated termination
of our or a third party's existing coal supply agreement in exchange for a cash
payment.
Depreciation, Depletion and Amortization. Fiscal year 2001 depreciation,
depletion and amortization expense was $241.0 million, a decrease of $8.8
million compared to fiscal year 2000. The decrease was primarily due to $6.0
million of additional depletion associated with a new coal royalty agreement
entered into in fiscal year 2000.
Selling and Administrative Expenses. Selling and administrative expenses
increased $4.0 million in fiscal year 2001 to $99.3 million. This increase was
primarily related to $3.7 million of increased stock compensation expense in
fiscal year 2001 related to the grant of Class B common stock to management.
Gain on Sale of Australian Operations. On January 29, 2001, we sold our
Australian operations to Coal & Allied, a 71%-owned subsidiary of Rio Tinto
Limited. The selling price was $446.8 million, plus the assumption of all
liabilities, including $119.4 million of debt. We recorded pretax gain of $171.7
million on the sale.
Operating Profit. Fiscal year 2001 operating profit was $341.8 million, an
increase of $148.6 million compared to fiscal year 2000. Excluding the gain on
the sale of our Australian operations, operating profit was $170.1 million, a
decrease of $23.1 million from fiscal year 2000. Operating margin excluding the
gain on the sale of our Australian operations was 6.6% in fiscal year 2001, a
decrease from 7.4% in fiscal year 2000. A 41% increase in fuel prices in fiscal
year 2001 decreased operating margin by 1.0% and operating profit by $24.1
million in fiscal year 2001. At our U.S. mining operations, operating profit,
excluding fuel cost variances, remained stable in fiscal year 2001.
Operating profit in the Powder River Basin region increased $20.5 million
primarily due to higher pricing in fiscal year 2001, combined with slightly
improved sales volume. In the Southwest region, we realized increased operating
profit of $12.1 million as a result of improved productivity and higher sales
volume in fiscal year 2001. Offsetting these increases was a $40.0 million
decrease in the Midwest region associated with the closure and suspension of
three mines in fiscal year 2000 and the closure of another mine early in the
third quarter of fiscal year 2001. Black Beauty's operating profit decreased
$18.5 million due to lower contract restructuring revenues in fiscal year 2001,
higher operating costs caused by adverse geologic conditions encountered during
the first nine months of the year as we transitioned to new mining areas and
unfavorable weather conditions, which delayed production and transportation of
coal. Appalachia's operating profit decreased $6.5 million due to poor mining
conditions at certain underground operations and lower average pricing in the
first nine months of fiscal year 2001 due to contract expirations, partially
offset by improved performance at the region's longwall operations.
Fiscal year 2001 results also included a decrease in operating costs for an
$8.0 million reduction in our liabilities for environmental cleanup-related
costs based upon favorable experience and lower costs of $9.1 million related to
Black Lung excise tax refund credits on export shipments. Beginning in 1997, we
filed for a refund of these taxes on the basis that the tax was
unconstitutional. In May 2000, the Internal Revenue Service issued guidelines
for the refund of these taxes. We have filed a claim and expect to receive a
refund in the first half of fiscal year 2002.
Operating costs also decreased $11.4 million in fiscal year 2001 due to the
reduction in our liability associated with the United Mine Workers of America
Combined Fund. The Coal Industry Retiree Health Benefit Act of 1992 established
the Combined Fund to provide for the funding of specified health benefits for
covered United Mine Workers of America retirees. Two of our subsidiaries filed a
lawsuit against the Social Security Administration asserting that it improperly
assigned certain beneficiaries to them. A federal District Court ruled in our
favor. Effective October 1, 2000, the Social Security Administration withdrew
the assignment to our subsidiaries of a specified number of beneficiaries,
resulting in a $11.4 million reduction in our liability.
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Additionally, our Australian operations' operating profit increased $5.0
million in fiscal year 2001.
Interest Expense. Interest expense decreased $7.4 million to $197.7 million
in fiscal year 2001. The decrease was primarily due to a $7.7 million decrease
in interest expense in the fourth quarter resulting from the repayment of $455.0
million of term loans under our senior credit facilities during the quarter, and
the removal of $119.4 million of debt from our balance sheet as a result of the
sale of our Australian operations.
Interest Income. Interest income increased $4.3 million to $8.7 million in
fiscal year 2001, primarily as a result of the interest income recorded in the
current year associated with the Black Lung excise tax refunds.
Income Taxes. Fiscal year 2001 income tax expense was $42.7 million on
pretax income of $152.9 million, compared to an income tax benefit of $141.5
million on a pretax loss of $7.4 million in fiscal year 2000. Additionally, in
fiscal year 2000 we recorded a $144.0 million income tax benefit associated with
an increase in the tax basis of a subsidiary's assets due to a change in federal
income tax regulations.
Our consolidated tax position is impacted by the percentage depletion tax
deduction utilized by us and our U.S. subsidiaries that creates an alternative
minimum tax situation, and the positive contribution of our Australian
operations, which are taxed at a higher rate than our U.S. operations.
Additionally, in fiscal year 2001 we recorded a $47.5 million tax provision
related to the gain on sale of our Australian operations. Excluding the tax
provision related to the sale of our Australian operations, the income tax
benefit recorded on U.S. pretax losses exceeded the Australian income tax
expense in fiscal year 2001 by $4.8 million.
Minority Interests. In fiscal year 2001, minority interest expense
decreased $8.0 million to $7.5 million, due to lower fiscal year 2001 results at
our 81.7%-owned Black Beauty operations. As discussed above, Black Beauty's
results were affected by a contract restructuring gain in fiscal year 2000,
combined with higher mining costs due to poor geologic conditions and higher
fuel costs in fiscal year 2001.
Loss from Discontinued Operations. In fiscal year 2000, Citizens Power
incurred a loss from operations of $12.1 million. Citizens Power was classified
as a discontinued operation in March 2000.
Gain from Disposal of Discontinued Operations. During fiscal year 2001, we
reduced our estimated net loss from the sale of Citizens Power by $12.9 million,
net of income taxes. This reduction reflected a decrease in the estimated
operating losses of Citizens Power during the disposal period due to higher
income from electricity trading activities driven by increased volatility and
prices for electricity in the western U.S. power markets during the first
quarter ($8.8 million) and higher estimated proceeds from the monetization of
power contracts as part of the wind-up of our ownership of Citizens Powers'
operations ($4.1 million). We completed the sale of Citizens Power in fiscal
year 2001.
Extraordinary Loss from the Early Extinguishment of Debt. In the fourth
quarter of fiscal year 2001, we made optional prepayments of term loans under
our senior credit facilities. These prepayments were primarily funded with the
proceeds from the sale of our Australian operations. The prepayments resulted in
an extraordinary loss of $8.5 million, net of income taxes, due to the write-off
of costs related to the issuance of the debt repaid.
FISCAL YEAR ENDED MARCH 31, 2000 COMPARED TO TOTAL FISCAL YEAR 1999
Sales. For fiscal year 2000, sales increased $361.1 million, or 16.0%, to
$2.6 billion. Sales volume increased 8.1% over the prior year. The fiscal year
2000 results included an increase attributable to Black Beauty of $428.9
million, which was principally comprised of two amounts: the inclusion of Black
Beauty's results for an entire year ($264.1 million) and the consolidation of
Sugar Camp, Arclar and United Minerals on a retroactive basis ($164.8 million).
The average sales price per ton increased 7.4% in 2000 due to this inclusion of
sales of Black Beauty and its affiliates and higher prices in the Powder River
Basin. Sales in Australia increased $75.5 million over total fiscal year 1999.
Powder River Basin sales increased $13.1 million, due mainly to a
continuing improvement in pricing for the low sulfur coal in this region.
Offsetting these increases were declines in the Midwest and Appalachia markets
of $68.1 million and $53.8 million, respectively. Both regions were negatively
impacted by mild winter weather that increased customer coal stockpiles, causing
lower demand and pricing. Sales in the Midwest region declined primarily due to
the closure and
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suspension of three high sulfur mines in fiscal year 2000, while results in
Appalachia were hampered by price reductions for coal utilized by the export
metallurgical market, and operating difficulties related to longwall panel
development delays and adverse geological conditions. Brokerage and trading
revenues declined $33.5 million, mainly due to new contracts with lower prices
than expiring contracts.
Other Revenues. Other revenues improved $1.9 million compared to fiscal
year 1999. This increase was primarily due to a $13.0 million gain from a
contract restructuring in which Black Beauty initiated the buyout of a
customer's contract in order to provide additional production capacity to meet a
new long-term coal supply agreement, and a $3.9 million gain on the settlement
of a contract dispute in the fourth quarter of fiscal year 2000, partially
offset by the exclusion of $7.5 million of equity income in affiliates
subsequently consolidated by Black Beauty as discussed above.
Selling and Administrative Expenses. Selling and administrative expenses
increased $6.4 million in fiscal year 2000 to $95.3 million. This increase was
the result of the inclusion of a full year of Black Beauty's operations,
compared to three months in fiscal year 1999 (an increase of $9.9 million) and
full year consolidation of Black Beauty affiliates previously mentioned,
partially offset by $13.1 million of compensation expense in fiscal year 1999
related to the grant of 992,276 shares of Class B common stock to management.
Operating Profit. Operating profit was $193.2 million for fiscal year 2000,
an increase of $26.8 million, or 16.1%. The impact of Black Beauty on fiscal
year 2000 results increased operating profit by $43.8 million, including a $13.0
million gain from the Black Beauty contract restructuring previously mentioned.
We also had $12.8 million less stock compensation expense in fiscal year 2000
than in fiscal year 1999.
Other regions showing year-over-year improvement were the Midwest ($15.0
million), Powder River Basin ($13.2 million) and Australia ($12.8 million). The
Midwest region improved over fiscal year 1999 as a result of lower reclamation
costs occurring from a change in permitting requirements in fiscal year 2000
($5.1 million), improved productivity and higher volume at the ongoing
Midwestern operations, partially offset by lower volumes due to the
closure/suspension of three mines in fiscal year 2000. Profit improved in the
Powder River Basin based upon higher pricing and higher demand for coal from our
lowest cost, most efficient operations. Our Australian operations also reported
higher profit.
Offsetting these increases were decreases in Appalachia ($32.1 million) and
the Southwest ($4.1 million). Profitability in Appalachia was directly impacted
by soft market conditions and higher costs as a result of longwall panel
development delays. The decline in the Southwest region was the result of higher
operating expenses, primarily as a result of higher repair and maintenance
expenses than in fiscal year 1999, offset partially by higher volumes and a gain
of $3.9 million from the settlement of a customer contractual dispute. In
addition, income from brokerage and trading activities decreased $19.8 million,
mainly as a result of lower volumes that were directly related to contract
expirations. Finally, we experienced higher costs for past mining obligations
due to the fiscal year 2000 cost of mine closure and suspension in the Midwest
region, and $14.0 million in higher administrative costs as a result of the
inclusion of Black Beauty and its affiliates.
Interest Expense. Interest expense for fiscal year 2000 was $205.1 million,
an increase of $24.8 million, or 13.8%. Fiscal year 1999 included
acquisition-related indebtedness from the May 19, 1998 acquisition of our
predecessor company forward. Also affecting fiscal year 2000 was the inclusion
of $12.6 million of additional interest associated with the consolidation of
Black Beauty.
Interest Income. Interest income decreased $15.8 million from fiscal year
1999 to $4.4 million. The decrease was primarily attributable to interest income
from higher average cash balances held in fiscal year 1999 in anticipation of
the acquisition of an additional ownership interest in Black Beauty that
occurred late in fiscal year 1999.
Income Taxes. For fiscal year 2000, we recorded an income tax benefit of
$141.5 million on a pretax loss from continuing operations of $7.4 million,
compared to an income tax expense of $7.5 million on pretax income from
continuing operations of $6.2 million in fiscal year 1999. The fiscal year 2000
amount reflected a $144.0 million income tax benefit associated with an election
to treat Peabody Natural Resources Company, our subsidiary, as a corporation
rather than as a partnership for federal income tax purposes. This election,
which became available through a change in tax law that occurred in December
1999, resulted in an increase in the tax basis in the entity's assets and
eliminated the necessity for a deferred tax liability that had reflected the
excess of the book basis in that subsidiary over the tax basis.
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Our effective book income tax rate was primarily impacted by two factors:
the percentage depletion tax deduction used by us and our U.S. subsidiaries that
creates an alternative minimum tax situation and the level of contribution by
the Australian operations to the consolidated results of operations, which is
taxed at a higher rate than in the United States.
Loss From Discontinued Operations. In fiscal year 2000, our discontinued
operations reported a net loss of $12.1 million, compared to net income of $4.7
million in fiscal year 1999. The decrease was largely the result of a decline in
the number of utility contract restructuring transactions completed in fiscal
year 2000 compared to fiscal year 1999. In addition, fiscal year 2000 results
included the estimated after-tax loss on disposal of Citizens Power of $78.3
million.
LONG-TERM COAL SUPPLY AGREEMENTS
As of March 31, 2001, nearly one billion tons of our future coal production
were committed under long-term contracts. Our strategy is to selectively renew,
or enter into new, long-term supply contracts when we can do so at favorable
prices. Long-term contracts may be particularly attractive in regions where
market prices are expected to remain stable, with respect to high sulfur coal
that would otherwise not be in great demand or for sales under cost-plus
arrangements serving captive electric generating plants. Prices for coal have
recently risen, particularly in the Powder River Basin and in Appalachia,
primarily due to increased prices for competing fuels and increased demand for
electricity. To the extent we do not renew or replace expiring long-term coal
supply agreements, our future sales will be exposed to market fluctuations,
including unexpected downturns in market prices. Most of the contracts contain
price adjustments for inflation and changes in the laws regulating the mining,
production, sale or use of coal. In the majority of these contracts, the
purchaser has the right to terminate the contract if the price increases beyond
certain limits, although we can usually decrease the price in order to maintain
the contract.
LIQUIDITY AND CAPITAL RESOURCES
Net cash provided by operating activities decreased by $110.9 million, to
$152.0 million, for fiscal year 2001. The decrease in net cash provided by
operating activities was primarily due to $60.0 million of lower proceeds from
the sale of accounts receivable in fiscal year 2001, combined with lower
operating cash flow from our Australian operations.
In March 2000, we established a five-year accounts receivable
securitization program under which we sell, without recourse, on an ongoing
basis, undivided interests in trade accounts receivable from our domestic
subsidiaries other than Black Beauty to a multi-seller, asset-backed commercial
paper conduit. The qualified pool of receivables included in the securitization
program includes customers with good credit ratings and is reduced for certain
items, including past due balances and specified concentration limits. The
conduit's purchases are financed with the sale of highly-rated commercial paper,
allowing us to lower our overall financing costs. The commercial paper is
secured by high-quality current trade receivables. The qualified pool of
accounts receivable subject to the program represented approximately 56% of our
total accounts receivable at March 31, 2001. Outstanding undivided interests
totaled $100.0 million at March 31, 2000 and $140.0 million at March 31, 2001.
Net cash provided by investing activities was $388.5 million for fiscal
year 2001, an increase of $573.9 million compared to fiscal year 2000. In fiscal
year 2001, we received $455.0 million in proceeds from the sale of our
Australian operations and $102.5 million in net proceeds from the sale of
Citizens Power, while fiscal year 2000 included higher expenditures for
acquisitions, partially offset by $32.9 million in proceeds from contract
restructurings.
Total capital expenditures for fiscal years 2001, 2000 and 1999 were $187.1
million, $178.8 million and $195.4 million, respectively. Of these capital
expenditures, $35.7 million, $28.6 million and $71.2 million relate to our
Australian operations. Our capital expenditures are primarily made to acquire
additional reserves and mining equipment. We currently estimate that our capital
expenditures for fiscal year 2002 will be $198.0 million and will primarily be
used to acquire additional coal reserves, develop existing reserves, replace
equipment and fund cost reduction initiatives. We had $94.4 million of future
committed capital expenditures at March 31, 2001 that are primarily related to
acquiring additional Powder River Basin coal reserves and mining equipment in
fiscal year 2002. We anticipate funding these capital expenditures through
available cash and credit facilities.
Net cash used in financing activities was $543.3 million for fiscal year
2001, compared to $205.2 million in fiscal year 2000. We used the net proceeds
from the sales of Citizens Power and our Australian operations to repay $633.9
million of long-term debt during fiscal year 2001, an increase of $423.9 million
in our debt repayments compared to fiscal year 2000.
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Effective May 20, 1998, we paid The Energy Group PLC $2,003.5 million in
cash for P&L Coal Group. The acquisition was financed by a $480.0 million equity
contribution by Lehman Brothers Merchant Banking and affiliates and borrowings
of $1,523.5 million. We also entered into a $480.0 million Senior Credit
Facility to provide for our working capital requirements following the
acquisition, with no initial borrowings related to financing the acquisition.
As of March 31, 2001, we had total indebtedness outstanding of $1,405.6
million that consisted of:
(In millions)
Term loans under our Senior Credit Facility......................................................... $ 125.0
Senior notes ....................................................................................... 399.1
Senior subordinated notes .......................................................................... 498.9
Indebtedness of Black Beauty subsidiary............................................................. 211.0
5.0% subordinated note.............................................................................. 169.9
Other long-term debt................................................................................ 1.7
--------
$1,405.6
========
The following table sets forth the mandatory repayments of our indebtedness
outstanding as of March 31, 2001:
FISCAL YEAR SENIOR CREDIT FACILITY 5.0% SUBORDINATED NOTE OTHER TOTAL
------------------------------------ ---------------------- ---------------------- --------- --------
(In millions)
2002................................ $ -- $ 20.0 $ 16.3 $ 36.3
2003................................ -- 20.0 37.7 57.7
2004................................ -- 20.0 50.2 70.2
2005................................ -- 20.0 85.6 105.6
2006................................ -- 20.0 7.9 27.9
2007 and thereafter................. 125.0 120.0 862.9 1,107.9
------ ------ -------- --------
$125.0 $220.0 $1,060.6 $1,405.6
====== ====== ======== ========
Our Senior Credit Facility includes a revolving credit facility that
currently provides for aggregate borrowings of up to $200.0 million and letters
of credit of up to $280.0 million. The revolving credit facility commitment
matures in fiscal year 2005. As of March 31, 2001, we had no borrowings
outstanding under the revolving credit facility. Revolving loans under the
revolving credit facility bear interest based on the base rate (as defined in
the Senior Credit Facility), or LIBOR (as defined in the Senior Credit Facility)
at our option. As of March 31, 2001, we had $73.4 million of letters of credit
outstanding under the revolving credit facility.
The revolving credit facility and related term loan facility also currently
contain restrictions and limitations including, but not limited to, financial
covenants that require us to maintain and achieve certain levels of financial
performance and prohibit the payment of cash dividends and similar restricted
payments.
The indentures governing the Senior Notes and Senior Subordinated Notes
permit us and our restricted subsidiaries to incur additional indebtedness,
including secured indebtedness, subject to certain limitations. In addition, the
indentures limit our ability to:
- pay dividends or make other distributions;
- lease, convey or otherwise dispose of all or substantially all of our
assets;
- issue specified types of capital stock;
- enter into guarantees of indebtedness;
- incur liens;
- restrict our subsidiaries' ability to make dividend payments;
- merge or consolidate with any other person or enter into transactions
with affiliates; and
- repurchase junior securities or make specified types of investments.
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As of March 31, 2001, Black Beauty maintained a $100.0 million revolving
credit facility that matures on February 28, 2002. Black Beauty may elect one or
a combination of interest rates based on LIBOR or the corporate base rate plus a
margin, which fluctuates based on specified leverage ratios. Borrowings
outstanding under the Black Beauty revolving credit agreement totaled $70.0
million at March 31, 2001. The revolving credit facility contains customary
restrictive covenants, including limitations on additional debt, investments and
dividends. In addition, Black Beauty's ability to pay dividends is subject to
certain financial tests.
Black Beauty's senior unsecured notes include $31.4 million of Senior Notes
and three series of notes with an aggregate principal amount of $60.0 million as
of March 31, 2001. The Senior Notes bear interest at 9.2%, payable quarterly,
and are prepayable in whole or in part at any time, subject to certain
make-whole provisions. The three series of notes include Series A, B and C
notes, totaling $45.0 million, $5.0 million and $10.0 million, respectively. The
Series A notes bear interest at an annual rate of 7.5% and are due in fiscal
year 2008. The Series B notes bear interest at an annual rate of 7.4% and are
due in fiscal year 2004. The Series C notes bear interest at an annual rate of
7.4% and are due in fiscal year 2003. The senior unsecured notes contain
customary restrictive covenants, including limitations on additional debt,
investments and dividends.
As of March 31, 2001, the revolving and working capital borrowing
facilities referred to above totaled $300.0 million, and borrowings thereunder
totaled $70.0 million. We were in compliance with the restrictive debt covenants
of all of our debt agreements as of March 31, 2001.
Subsidiaries of Black Beauty maintain borrowing facilities with banks and
other lenders with customary restrictive covenants. The aggregate amount of
outstanding indebtedness under those facilities totaled $47.8 million as of
March 31, 2001.
On January 29, 2001, we received $455.0 million in cash, prior to
post-closing adjustments of $8.2 million, from the sale of our Australian
operations. Using these proceeds, we repaid the remaining $110.0 million of the
tranche A term loan and $345.0 million of the tranche B term loan outstanding
under our Senior Credit Facility. After giving effect to those repayments, we
had no tranche A term loans outstanding and $125.0 million of tranche B term
loans outstanding.
On May 22, 2001, we completed an initial public offering of 17,250,000
shares of common stock. Net proceeds from the offering were $451.8 million. In
connection with the offering, we repaid the remaining tranche B term loan
outstanding under the Senior Credit Facility of $125.0 million and used $100.0
million to repay borrowings under our revolving credit facility that were used
to repay a portion of our 5% subordinated note. We also used $173.0 million of
proceeds from the offering to repurchase $80.0 million in principal amount of
our Senior Notes and $80.0 million in principal amount of our Senior
Subordinated Notes pursuant to a previously announced tender offer. In addition,
we used $3.1 million and $12.7 million of proceeds to repurchase $2.9 million in
principal amount of our Senior Notes and $11.7 million in principal amount of
our Senior Subordinated Notes, respectively, in a private transaction. The
remaining proceeds from the initial public offering of $38.0 million will be
used for the repayment of additional debt and/or for general corporate purposes.
Subsequent to March 31, 2001, we received the approval from a sufficient
number of our lenders to amend our Senior Credit Facility. The amendment, which
became effective at the time of the offering, permits the payment of cash
dividends and other restricted payments subject to specified limitations,
increases the amount available for borrowing under the revolving credit facility
from $200.0 million to $350.0 million and permits additional joint venture
investments. In connection with the amendment, we agreed to reduce the maximum
permitted debt to EBITDA ratio and increase the minimum required interest
coverage ratio. We paid an amendment fee of $1.4 million to a group of over 100
lenders who consented to the amendment. All other terms and conditions remained
unchanged.
Black Beauty replaced its $100.0 million revolving credit facility with a
new $120.0 million revolving credit facility on April 16, 2001. The new facility
contains substantially similar restrictive covenants and matures on April 17,
2004. Borrowings outstanding under the $100.0 million revolving credit facility
on April 16, 2001 were refinanced under the new $120.0 million revolving credit
facility.
CERTAIN LIABILITIES
We have significant long-term liabilities relating to mine reclamation,
work-related injuries and illnesses, pensions and retiree health care. Accruals
for these liabilities reflect U.S. coal industry and generally accepted
accounting principles. Our operations and the operations of our predecessor
subject us to liability for the investigation and remediation of releases of
hazardous substances into the environment and for damages to natural resources
under Superfund and similar state laws. The
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majority of our existing liabilities relate to our past operations, which had
more mines and employees than we currently have. Our aggregate cash payments for
these liabilities for fiscal year 2001 were $149.0 million.
In connection with the sale of Citizens Power, we have indemnified the
buyer from certain losses resulting from specified power contracts and
guarantees. No claims have been asserted against us under this indemnity.
RECENT ACCOUNTING PRONOUNCEMENTS
In June 1998, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 133, "Accounting for Derivative Instruments
and Hedging Activities." Statement of Financial Accounting Standards No. 133 (as
amended by Statement of Financial Accounting Standards Nos. 137 and 138)
requires the recognition of all derivatives as assets or liabilities within the
balance sheet and requires both the derivatives and the underlying exposure to
be recorded at fair value. Any gain or loss resulting from changes in fair value
will be recorded as part of the results of operations, or as a component of
comprehensive income or loss, depending upon the intended use of the derivative.
The effective date of Statement of Financial Accounting Standards No. 133 is for
all fiscal quarters of fiscal years beginning after June 15, 2000 (effective
April 1, 2001 for us). We do not anticipate that the adoption of Statement of
Financial Accounting Standards No. 133 will have a material effect on our
financial condition or results of operations, subject to new or revised
implementation guidelines issued by the Derivatives Implementation Group.
INVESTMENT CONSIDERATIONS
Reliance on Long-Term Coal Supply Agreements
A substantial portion of our sales are made under coal supply agreements,
which are important to the stability and profitability of our operations. The
execution of a satisfactory coal supply agreement is frequently the basis on
which we undertake the development of coal reserves required to be supplied
under the contract. For fiscal year 2001, 85% of our sales volume was sold under
long-term coal supply agreements. At March 31, 2001, our coal supply agreements
had remaining terms ranging from one to 16 years and an average volume-weighted
remaining term of four years.
Many of our coal supply agreements contain provisions that permit the
parties to adjust the contract price upward or downward at specified times. We
may adjust these contract prices based on inflation and/or changes in the
factors affecting the cost of producing coal, such as taxes, fees, royalties and
changes in the laws regulating the mining, production, sale or use of coal.
Failure of the parties to agree on a price under those provisions may allow
either party to terminate the contract. Over the last few years, several of our
coal supply agreements have been renegotiated, resulting in the contract prices
being closer to the then-current market prices, thus leading to a reduction in
the revenues from those contracts. We have also experienced a similar reduction
in coal prices in new long-term coal supply agreements replacing some of our
expiring contracts. 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 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 these agreements permit the customer to terminate the contract
if transportation costs, which our customers typically bear, increase
substantially. In addition, a majority of these contracts allow our customers to
terminate their contracts in the event of changes in regulations affecting our
industry that increase the price of coal beyond specified limits.
The operating profits we realize from coal sold under supply agreements
depend on a variety of factors. In addition, price adjustment and other
provisions may increase our exposure to short-term coal price volatility
provided by those contracts. If a substantial portion of our coal supply
agreements were modified or terminated, we could be materially adversely
affected to the extent that we are unable to find alternate buyers for our coal
at the same level of profitability. Some of our coal supply agreements are for
prices above current market prices. Although market prices for coal have
recently increased in most regions, we cannot predict whether the current
strength in the coal market will continue. As a result, we cannot assure you
that we will be able to replace existing long-term coal supply agreements at the
same prices or with similar profit margins when they expire. In addition, two of
our coal supply agreements are the subject of ongoing litigation and
arbitration.
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Dependence on Major Customers
For fiscal year 2001, we derived 36% of our total coal revenues from sales
to our five largest customers. At March 31, 2001, we had 18 coal supply
agreements with these customers that expire at various times from 2001 to 2015.
We are currently discussing the extension of existing agreements or entering
into new long-term agreements with some of these customers, but these
negotiations may not be successful and those customers may not continue to
purchase coal from us under long-term coal supply agreements. If a number of
these customers were to significantly reduce their purchases of coal from us, or
if we were unable to sell coal to them on terms as favorable to us as the terms
under our current agreements, our financial condition and results of operations
could suffer materially.
Substantial Leverage
Our financial performance could be affected by our substantial
indebtedness. As of March 31, 2001, we had total indebtedness of $1,405.6
million that subsequently was reduced by $415.0 million from proceeds of the
initial public offering. In addition, after consummation of the offering we have
total borrowing capacity under our and Black Beauty's revolving credit
facilities of $470.0 million. We may also incur additional indebtedness in the
future.
Our ability to pay principal and interest on our debt depends upon the
operating performance of our subsidiaries, which will be affected by, among
other things, prevailing economic conditions in the markets they serve, some of
which are beyond our control. Our business may not generate sufficient cash flow
from operations and future borrowings may not be available under our revolving
credit facilities or otherwise in an amount sufficient to enable us to service
our indebtedness or to fund our other liquidity needs.
The degree to which we are leveraged could have important consequences to
you, including, but not limited to: (1) making it more difficult for us to pay
dividends and satisfy our debt obligations; (2) increasing our vulnerability to
general adverse economic and industry conditions; (3) requiring the dedication
of a substantial portion of our cash flow from operations to the payment of
principal of, and interest on, our indebtedness, thereby reducing the
availability of the cash flow to fund working capital, capital expenditures,
research and development or other general corporate uses; (4) limiting our
ability to obtain additional financing to fund future working capital, capital
expenditures, research and development or other general corporate requirements;
(5) limiting our flexibility in planning for, or reacting to, changes in our
business; and (6) placing us at a competitive disadvantage compared to less
leveraged competitors. In addition, our indebtedness subjects us to financial
and other restrictive covenants. Failure by us to comply with these covenants
could result in an event of default which, if not cured or waived, could have a
material adverse effect on us. Furthermore, substantially all of our assets
secure our indebtedness under our Senior Credit Facility.
Transportation
Transportation costs represent a significant portion of the total cost of
coal, and as a result, the cost of transportation is a critical factor in a
customer's purchasing decision. Increases in transportation costs could make
coal a less competitive source of energy or could make some of our operations
less competitive than other sources of coal. Certain coal supply agreements
permit the customer to terminate the contract if the cost of transportation
increases by an amount ranging from 10% to 20% in any given 12-month period.
Coal producers depend upon rail, barge, trucking, overland conveyor and
other systems to deliver coal to markets. While U.S. coal customers typically
arrange and pay for transportation of coal from the mine to the point of use,
disruption of these transportation services because of weather-related problems,
strikes, lock-outs or other events could temporarily impair our ability to
supply coal to our customers and thus could adversely affect our results of
operations. For example, the high volume of coal shipped from all Southern
Powder River Basin mines could create temporary congestion on the rail systems
servicing that region.
Risks Inherent to Mining
Our mining operations are subject to conditions beyond our control that can
delay coal deliveries or increase the cost of mining at particular mines for
varying lengths of time. These conditions include weather and natural disasters,
unexpected maintenance problems, key equipment failures, variations in coal seam
thickness, variations in the amount of rock and soil overlying the coal deposit,
variations in rock and other natural materials and variations in geologic
conditions.
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Government Regulation of the Mining Industry
Federal, state and local authorities regulate the coal mining industry with
respect to matters such as employee health and safety, permitting and licensing
requirements, air quality standards, water pollution, plant and wildlife
protection, reclamation and restoration of mining properties after mining is
completed, the discharge of materials into the environment, surface subsidence
from underground mining and the effects that mining has on groundwater quality
and availability. In addition, significant legislation mandating specified
benefits for retired coal miners affects our industry. Numerous governmental
permits and approvals are required for mining operations. We are required to
prepare and present to federal, state or local authorities data pertaining to
the effect or impact that any proposed exploration for or production of coal may
have upon the environment. The costs, liabilities and requirements associated
with these regulations may be costly and time-consuming and may delay
commencement or continuation of exploration or production operations. The
possibility exists that new legislation and/or regulations and orders may be
adopted that may materially adversely affect our mining operations, our cost
structure and/or our customers' ability to use coal. New legislation or
administrative regulations (or judicial interpretations of existing laws and
regulations), including proposals related to the protection of the environment
that would further regulate and tax the coal industry, may also require us or
our customers to change operations significantly or incur increased costs. The
majority of our coal supply agreements contain provisions that allow a purchaser
to terminate its contract if legislation is passed that either restricts the use
or type of coal permissible at the purchaser's plant or results in specified
increases in the cost of coal or its use. These factors and legislation, if
enacted, could have a material adverse effect on our financial condition and
results of operations.
Kyoto Protocol
The United States and over 160 other nations are signatories to the 1992
Framework Convention on Climate Change, which is intended to limit emissions of
greenhouse gases, such as carbon dioxide. In December 1997, in Kyoto, Japan, the
signatories to the convention established a binding set of emission targets for
developed nations. Although the specific emission targets vary from country to
country, the United States would be required to reduce emissions to 93% of 1990
levels over a five-year budget period from 2008 through 2012. Although the
United States has not ratified the emission targets and no comprehensive
regulations focusing on greenhouse gas emissions are in place, these
restrictions, whether through ratification of the emission targets or other
efforts to stabilize or reduce greenhouse gas emissions, could adversely impact
the price and demand for coal. According to the Energy Information
Administration's Emissions of Greenhouse Gases in the United States 1999, coal
accounts for 30% of greenhouse gas emissions in the United States, and efforts
to control greenhouse gas emissions could result in reduced use of coal if
electricity generators switch to sources of fuel with lower carbon dioxide
emissions. Further developments in connection with the Kyoto Protocol could have
a material adverse effect on our financial condition or results of operations.
Postretirement Benefit and Pension Obligations
We provide postretirement health and life insurance benefits to eligible
union and non-union employees. We calculated the total accumulated
postretirement benefit obligation under Statement of Financial Accounting
Standards No. 106, "Employers' Accounting for Postretirement Benefits Other Than
Pensions," which we estimate had a present value of $1,036.1 million as of March
31, 2001, of which $62.0 million was a current liability. We have estimated
these unfunded obligations based on assumptions described in Note 14 to our
audited financial statements. If our assumptions do not materialize as expected,
cash expenditures and costs that we incur could be materially higher. Moreover,
regulatory changes could increase our obligations to provide these or additional
benefits.
We are party to an agreement with the Pension Benefit Guaranty Corporation,
or the PBGC, and TXU Europe Limited, an affiliate of our former parent
corporation, under which we are required to make specified contributions to
three of our defined benefit pension plans and to maintain a $37.0 million
letter of credit in favor of the PBGC. If we or the PBGC gives notice of an
intent to terminate one or more of the covered pension plans in which
liabilities are not fully funded, or if we fail to maintain the letter of
credit, the PBGC may draw down on the letter of credit and use the proceeds to
satisfy liabilities under the Employee Retirement Income Security Act of 1974,
as amended. The PBGC, however, is required to first apply amounts received from
a $110.0 million guaranty in place from TXU Europe Limited in favor of the PBGC
before it draws on our letter of credit.
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Replacement and Recoverability of Reserves
Our recoverable reserves decline as we produce coal. We have not yet
applied for the permits required or developed the mines necessary to use all of
our reserves. Furthermore, we may not be able to mine all of our reserves as
profitably as we do at our current operations. Our future success depends upon
our conducting successful exploration and development activities or acquiring
properties containing economically recoverable reserves. Our current strategy
includes increasing our reserve base through acquisitions of government and
other leases and producing properties and continuing to use our existing
properties. The federal government also leases natural gas and coalbed methane
reserves in the west, including in the Powder River Basin. Some of these natural
gas and coalbed methane reserves are located on, or adjacent to, some of our
Powder River Basin reserves, potentially creating conflicting interests between
us and lessees of those interests. Other lessees' rights relating to these
mineral interests could prevent, delay or increase the cost of developing our
coal reserves. These lessees may also seek damages from us based on claims that
our coal mining operations impair their interests. Additionally, the federal
government limits the amount of federal land that may be leased by any company
to 150,000 acres nationwide. We currently lease or have applied to lease a total
of 64,805 acres from the federal government. The limit could restrict our
ability to lease additional federal lands.
Our planned development and exploration projects and acquisition activities
may not result in significant additional reserves and we may not have continuing
success developing additional mines. Most of our mining operations are conducted
on properties owned or leased by us. Because title to most of our leased
properties and mineral rights are not thoroughly verified until a permit to mine
the property is obtained, our right to mine some of our reserves may be
materially adversely affected if defects in title or boundaries exist. In
addition, in order to develop our reserves, we must receive various governmental
permits, as discussed in "Regulatory Matters." We cannot predict whether we will
continue to receive the permits necessary for us to operate profitably in the
future. We may not be able to negotiate new leases from the government or from
private parties or obtain mining contracts for properties containing additional
reserves or maintain our leasehold interest in properties on which mining
operations are not commenced during the term of the lease. From time to time, we
have experienced litigation with lessors of our coal properties and with royalty
holders.
Coal Industry Capacity
During the mid-1970s and early 1980s, a growing coal market and increased
demand for coal attracted new investors to the coal industry, spurred the
development of new mines and resulted in added production capacity throughout
the industry, all of which led to increased competition and lower coal prices.
Recent increases in coal prices could similarly encourage the development of
expanded capacity by new or existing coal producers. Any overcapacity could
reduce coal prices in the future.
Labor Force
As of March 31, 2001, the United Mine Workers of America represented
approximately 37% of our employees, who produced 23% of our coal sales volume in
the United States during fiscal year 2001. Because of the higher labor costs and
the increased risk of strikes and other work-related stoppages that may be
associated with union operations in the coal industry, our non-unionized
competitors may have a competitive advantage in areas where they compete with
our unionized operations. If some or all of our current non-union operations
were to become unionized, we could incur an increased risk of work stoppages,
reduced productivity and higher labor costs. The ten-month United Mine Workers
of America strike in 1993 had a material adverse effect on us. Two of our
subsidiaries, Peabody Coal Company and Eastern Associated Coal Corp., operate
under a union contract that is in effect through December 31, 2002. The United
Mine Workers of America has indicated an interest in seeking early negotiations
for a new contract, although none of the parties are required to do so. Peabody
Western Coal Company operates under a union contract that is in effect through
September 1, 2005.
Surety Bonds
Federal and state laws require bonds to secure our obligations to reclaim
lands used for mining, to pay federal and state workers' compensation and to
satisfy other miscellaneous obligations. As of March 31, 2001, we had
outstanding surety bonds with third parties for post-mining reclamation totaling
$651.8 million. Furthermore, we have an additional $77.4 million of surety bonds
in place for our federal and state workers' compensation obligations and other
miscellaneous obligations. These bonds are typically renewable on a yearly
basis. Surety bond issuers and holders may not continue to renew the bonds or
refrain from demanding additional collateral upon those renewals. Our failure to
maintain, or inability to
38
39
acquire, surety bonds that are required by state and federal law would have a
material adverse effect on us. That failure could result from a variety of
factors including the following:
- lack of availability, higher expense or unfavorable market terms of new
surety bonds;
- restrictions on the availability of collateral for current and future
third-party surety bond issuers under the terms of our indentures or
Senior Credit Facility; and
- the exercise by third-party surety bond issuers of their right to
refuse to renew the surety.
Lehman Brothers Merchant Banking
Lehman Brothers Merchant Banking owns 57% of our common stock. Lehman
Brothers Merchant Banking will continue to be able to control the election of
our directors and determine our corporate and management policies, including
potential mergers or acquisitions, asset sales and other significant corporate
transactions. The interests of Lehman Brothers Merchant Banking may not coincide
with the interests of other holders of our common stock. We have retained
affiliates of Lehman Brothers Merchant Banking to perform advisory and financing
services for us in the past, and may continue to do so in the future.
Dependence on Key Personnel
We manage our business with a number of key personnel, in particular the
executive officers discussed in "Item 10 - Directors and Executive Officers of
the Registrant," the loss of a number of whom could have a material adverse
effect on us. In addition, as our business develops and expands, we believe that
our future success will depend greatly on our continued ability to attract and
retain highly skilled and qualified personnel. We cannot assure you that key
personnel will continue to be employed by us or that we will be able to attract
and retain qualified personnel in the future. We do not have "key person" life
insurance to cover our executive officers. Failure to retain or attract key
personnel could have a material adverse effect on us.
39
40
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
Trading Activities
We market and trade coal and emission allowances. These activities give
rise to market risk, which represents the potential loss that can be caused by a
change in the market value of a particular commitment. We actively measure,
monitor and attempt to control market risks to ensure compliance with management
policies. For example, we have policies in place that limit the amount of total
exposure we may assume at any point in time.
We account for coal and emission allowance trading using the fair value
method, which requires us to reflect financial instruments with third parties,
such as forwards, futures, options and swaps, at market value in our
consolidated financial statements.
Non-trading Activities
We manage our commodity price risk for non-trading purposes through the use
of long-term coal supply agreements, rather than through the use of derivative
instruments. We sold approximately 85% of our sales volume under long-term coal
supply agreements during fiscal year 2001. Over the next few years, we
anticipate that an increasing portion of our coal sales will be made at
then-current market prices rather than under long-term coal supply agreements.
As a result, our revenues will be increasingly affected by fluctuations in the
price of coal.
Some of the products used in our mining activities, such as diesel fuel,
are subject to price volatility. We use forward contracts to manage the
volatility related to this exposure.
We have exposure to changes in interest rates due to our existing level of
indebtedness. As of March 31, 2001, we had $1,161.1 million of fixed-rate
borrowings and approximately $244.5 million of variable-rate borrowings
outstanding. A one percentage point increase in interest rates would result in
an annualized increase to interest expense of approximately $2.4 million on our
variable-rate borrowings. With respect to our fixed-rate borrowings, a 1%
increase in interest rates would result in a $61.3 million decrease in the fair
value of these borrowings.
40
41
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
INDEX TO FINANCIAL STATEMENTS
PAGE
----
Report of Independent Auditors........................................................................................ 42
Audited Financial Statements:
Statements of Operations--Years ended March 31, 2001 and 2000, period from May 20, 1998
to March 31, 1999, and period from April 1, 1998 to May 19, 1998................................................. 43
Balance Sheets--March 31, 2001 and 2000........................................................................... 44
Statements of Cash Flows--Years ended March 31, 2001 and 2000, period from May 20, 1998
to March 31, 1999, and period from April 1, 1998 to May 19, 1998................................................. 45
Statements of Changes in Stockholders' Equity/Invested Capital--Years ended March 31, 2001 and
2000, period from May 20, 1998 to March 31, 1999, and period from April 1, 1998 to May 19, 1998.................. 47
Notes to Financial Statements......................................................................................... 48
41
42
REPORT OF INDEPENDENT AUDITORS
Board of Directors
Peabody Energy Corporation
We have audited the accompanying consolidated balance sheets of Peabody
Energy Corporation (the Company), formerly P&L Coal Holdings Corporation, as of
March 31, 2001 and 2000, and the related consolidated statements of operations,
changes in stockholders' equity and cash flows of the Company for the years then
ended and the period from May 20, 1998 to March 31, 1999. We have also audited
the combined statements of operations, changes in invested capital and cash
flows of P&L Coal Group (the Predecessor Company) for the period from April 1,
1998 to May 19, 1998. These financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and perform
the audit to obtain reasonable assurance about whether the financial statements
are free of material misstatement. An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion the financial statements referred to above present fairly,
in all material respects, the consolidated financial position of Peabody Energy
Corporation at March 31, 2001 and 2000, the consolidated results of operations
and cash flows of the Company for the years ended March 31, 2001 and 2000 and
the period from May 20, 1998 to March 31, 1999, and the combined results of
operations and cash flows of the Predecessor Company for the period from April
1, 1998 to May 19, 1998 in conformity with accounting principles generally
accepted in the United States.
ERNST & YOUNG LLP
St. Louis, Missouri
April 20, 2001
except for the fourth
paragraph of Note 1
as to which the date
is May 17, 2001
42
43
PEABODY ENERGY CORPORATION
STATEMENTS OF OPERATIONS
(DOLLARS IN THOUSANDS, EXCEPT SHARE DATA)
PREDECESSOR
COMPANY
---------------
YEAR ENDED YEAR ENDED MAY 20, 1998 TO APRIL 1, 1998 TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- --------------- ----------------
REVENUES
Sales ........................................................ $ 2,579,104 $ 2,610,991 $ 1,970,957 $ 278,930
Other revenues ............................................... 90,588 99,509 85,875 11,728
------------ ------------ ------------ ------------
Total revenues ........................................... 2,669,692 2,710,500 2,056,832 290,658
COSTS AND EXPENSES
Operating costs and expenses ................................. 2,165,090 2,178,664 1,643,718 244,128
Depreciation, depletion and amortization ..................... 240,968 249,782 179,182 25,516
Selling and administrative expenses .......................... 99,267 95,256 76,888 12,017
Gain on sale of Australian operations ........................ (171,735) -- -- --
Net gain on property and equipment disposals ................. (5,737) (6,439) -- (328)
------------ ------------ ------------ ------------
OPERATING PROFIT ................................................. 341,839 193,237 157,044 9,325
Interest expense ............................................. 197,686 205,056 176,105 4,222
Interest income .............................................. (8,741) (4,421) (18,527) (1,667)
------------ ------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES AND
MINORITY INTERESTS ............................................. 152,894 (7,398) (534) 6,770
Income tax provision (benefit) ............................... 42,690 (141,522) 3,012 4,530
Minority interests ........................................... 7,524 15,554 1,887 --
------------ ------------ ------------ ------------
INCOME (LOSS) FROM CONTINUING OPERATIONS ......................... 102,680 118,570 (5,433) 2,240
(Income) loss from discontinued operations, net of
income tax provision (benefit) of ($1,297), $6,035 and
($189), respectively ....................................... -- 12,087 (6,442) 1,764
(Gain) loss from disposal of discontinued operations, net
of income tax provision (benefit) of $4,240 and
($31,188), respectively .................................... (12,925) 78,273 -- --
------------ ------------ ------------ ------------
INCOME BEFORE EXTRAORDINARY ITEM ................................. 115,605 28,210 1,009 476
Extraordinary loss from early extinguishment of debt, net
of income tax benefit of $2,480 ............................ 8,545 -- -- --
------------ ------------ ------------ ------------
NET INCOME ....................................................... $ 107,060 $ 28,210 $ 1,009 $ 476
============ ============ ============ ============
BASIC AND DILUTED EARNINGS (LOSS) PER
SHARE
Income (loss) from continuing operations ..................... $ 2.97 $ 3.43 $ (0.16)
Income (loss) from discontinued operations ................... 0.38 (2.61) 0.19
Extraordinary loss from early extinguishment of debt ......... (0.25) -- --
------------ ------------ ------------
Net income ................................................... $ 3.10 $ 0.82 $ 0.03
============ ============ ============
WEIGHTED AVERAGE SHARES OUTSTANDING .............................. 27,524,626 27,586,370 26,823,383
============ ============ ============
See accompanying notes to financial statements.
43
44
PEABODY ENERGY CORPORATION
BALANCE SHEETS
(DOLLARS IN THOUSANDS, EXCEPT SHARE DATA)
AS OF MARCH 31,
----------------------------
2000 2001
----------- -----------
ASSETS
Current assets
Cash and cash equivalents .................................................................. $ 62,723 $ 65,618
Accounts receivable, less allowance of $1,213 and $1,233, respectively ..................... 147,808 153,021
Materials and supplies ..................................................................... 38,733 48,809
Coal inventory ............................................................................. 171,479 193,341
Assets from coal and emission allowance trading activities ................................. 172,330 78,695
Deferred income taxes ...................................................................... 12,226 49,869
Other current assets ....................................................................... 24,656 43,192
----------- -----------
Total current assets ................................................................... 629,955 632,545
Property, plant, equipment and mine development
Land and coal interests .................................................................... 3,895,966 4,135,010
Building and improvements .................................................................. 332,428 350,284
Machinery and equipment .................................................................... 631,605 741,486
Less accumulated depreciation, depletion and amortization .................................. (537,360) (411,270)
----------- -----------
Property, plant, equipment and mine development, net ........................................... 4,322,639 4,815,510
Net assets of discontinued operations .......................................................... -- 90,000
Investments and other assets ................................................................... 256,893 288,794
----------- -----------
Total assets ....................................................................... $ 5,209,487 $ 5,826,849
=========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Short-term borrowings and current maturities of long-term debt ............................. $ 36,305 $ 57,977
Income taxes payable ....................................................................... 491 13,594
Liabilities from coal and emission allowance trading activities ............................ 163,713 75,883
Accounts payable and accrued expenses ...................................................... 576,476 573,137
----------- -----------
Total current liabilities .............................................................. 776,985 720,591
Long-term debt, less current maturities ........................................................ 1,369,316 2,018,189
Deferred income taxes .......................................................................... 570,705 625,124
Accrued reclamation and other environmental liabilities ........................................ 447,713 502,092
Workers' compensation obligations .............................................................. 210,780 212,260
Accrued postretirement benefit costs ........................................................... 974,079 971,186
Obligation to industry fund .................................................................... 52,172 64,737
Other noncurrent liabilities ................................................................... 135,041 162,979
----------- -----------
Total liabilities ...................................................................... 4,536,791 5,277,158
Minority interests ............................................................................. 41,458 41,265
Stockholders' equity
Preferred stock--$0.01 per share par value; 14,000,000 shares authorized,
7,000,000 shares issued and outstanding as of March 31, 2001 and 2000 .................... 50 50
Common stock--Class A, $0.01 per share par value; 42,000,000 shares authorized,
26,600,000 shares issued and outstanding as of March 31, 2001 and 2000 ................... 190 190
Common stock--Class B, $0.01 per share par value; 4,200,000 shares authorized,
1,033,490 shares issued and 1,010,509 shares outstanding as of March 31,
2001; 4,200,000 shares authorized, 1,039,176 shares issued and 958,263
shares outstanding as of March 31, 2000 .................................................. 8 7
Additional paid-in capital ................................................................. 498,198 494,237
Employee stock loans ....................................................................... (2,553) (2,391)
Accumulated other comprehensive loss ....................................................... (862) (12,667)
Retained earnings .......................................................................... 136,279 29,219
Treasury shares, at cost: 22,981 and 80,913 Class B shares as of March 31, 2001 and 2000 ... (72) (219)
----------- -----------
Total stockholders' equity ............................................................. 631,238 508,426
----------- -----------
Total liabilities and stockholders' equity ......................................... $ 5,209,487 $ 5,826,849
=========== ===========
See accompanying notes to financial statements.
44
45
PEABODY ENERGY CORPORATION
STATEMENTS OF CASH FLOWS
(DOLLARS IN THOUSANDS)
PREDECESSOR
COMPANY
----------------
YEAR ENDED YEAR ENDED MAY 20, 1998 TO APRIL 1, 1998 TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- --------------- --------------
CASH FLOWS FROM OPERATING ACTIVITIES
Net income ......................................................... $ 107,060 $ 28,210 $ 1,009 $ 476
(Income) loss from discontinued operations ..................... -- 12,087 (6,442) 1,764
(Gain) loss from disposal of discontinued operations ........... (12,925) 78,273 -- --
Extraordinary loss from early extinguishment of debt ........... 8,545 -- -- --
----------- ----------- ----------- -----------
Income (loss) from continuing operations ................... 102,680 118,570 (5,433) 2,240
Adjustments to reconcile income from continuing operations to net
cash provided by (used in) continuing operations:
Depreciation, depletion and amortization ....................... 215,450 249,782 179,182 25,516
Deferred income taxes .......................................... 31,795 (157,803) (679) 2,835
Amortization of debt discount and debt issuance costs .......... 16,709 18,911 16,120 1,379
Gain on sale of Australian operations .......................... (171,735) -- -- --
Net gain on property and equipment disposals ................... (4,782) (6,439) -- (328)
Gain on coal contract restructurings ........................... -- (12,957) (5,300) --
Stock compensation ............................................. 3,961 265 13,124 --
Minority interests ............................................. 7,524 15,554 1,887 --
Changes in current assets and liabilities, excluding effects of
acquisitions:
Sale of accounts receivable ................................ 40,000 100,000 -- --
Accounts receivable, net of sale ........................... (50,179) 18,712 20,164 (9,768)
Materials and supplies ..................................... 5,677 5,227 3,620 881
Coal inventory ............................................. (15,749) 10,774 5,781 (2,807)
Net assets from coal and emission allowance trading
activities ............................................... (5,805) (310) -- --
Other current assets ....................................... 6,912 (16,862) 7,459 (10,707)
Accounts payable and accrued expenses ...................... 51,659 (15,064) (50,373) (34,685)
Income taxes payable ....................................... 316 7,549 173 1,234
Accrued reclamation and related liabilities ........................ (35,080) (18,233) (4,468) (1,622)
Workers' compensation obligations .................................. (1,480) 4,716 (10,449) (2,156)
Accrued postretirement benefit costs ............................... (833) 14,472 6,094 6,092
Obligation to industry fund ........................................ (12,565) 1,630 (3,619) (2,379)
Royalty prepayment ................................................. -- -- 135,903 --
Other, net ......................................................... (12,371) (35,079) 21,737 (5,586)
Net cash used in assets sold--Australian operations ................ (20,124) -- -- --
----------- ----------- ----------- -----------
Net cash provided by (used in) continuing
operations ........................................... 151,980 303,415 330,923 (29,861)
Net cash provided by (used in) discontinued
operations ........................................... -- (40,504) (48,901) 1,704
----------- ----------- ----------- -----------
Net cash provided by (used in) operating activities .... 151,980 262,911 282,022 (28,157)
----------- ----------- ----------- -----------
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to property, plant, equipment and mine development ....... (151,358) (178,754) (174,520) (20,874)
Additions to advance mining royalties .............................. (20,260) (25,292) (11,509) (2,302)
Acquisitions, net .................................................. (10,502) (63,265) (2,110,400) --
Investment in joint venture ........................................ -- (4,325) -- --
Proceeds from coal contract restructurings ......................... -- 32,904 2,515 328
Proceeds from sale of Australian operations ........................ 455,000 -- -- --
Proceeds from property and equipment disposals ..................... 18,925 19,284 11,448 1,374
Proceeds from sale-leaseback transactions .......................... 28,800 34,234 -- --
Net cash used in assets sold--Australian operations ................ (34,684) -- -- --
----------- ----------- ----------- -----------
Net cash provided by (used in) continuing
operations ........................................... 285,921 (185,214) (2,282,466) (21,474)
Net cash provided by (used in) discontinued
operations ........................................... 102,541 (170) 33,130 (76)
----------- ----------- ----------- -----------
Net cash provided by (used in) investing activities .... 388,462 (185,384) (2,249,336) (21,550)
----------- ----------- ----------- -----------
(Continued on following page)
See accompanying notes to financial statements.
45
46
PEABODY ENERGY CORPORATION
STATEMENTS OF CASH FLOWS (CONTINUED)
(DOLLARS IN THOUSANDS)
PREDECESSOR
COMPANY
----------------
YEAR ENDED YEAR ENDED MAY 20, 1998 TO APRIL 1, 1998 TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- --------------- ----------------
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from short-term borrowings and long-term debt .......... 65,302 22,026 1,870,778 53,597
Payments of short-term borrowings and long-term debt ............ (633,905) (209,985) (222,715) (19,423)
Capital contribution ............................................ -- -- 480,000 --
Distributions to minority interests ............................. (4,690) (3,353) (3,080) --
Dividend received ............................................... 19,916 -- -- --
Dividends paid .................................................. -- -- -- (173,330)
Proceeds from sale of treasury stock ............................ 562 -- -- --
Repurchase of treasury stock .................................... (1,113) -- -- --
Net cash provided by assets sold--Australian operations ......... 10,591 -- -- --
Transactions with affiliates:
Proceeds from affiliated loan ............................... -- -- -- 141,000
Repayments to affiliates .................................... -- -- (3,647) --
Invested capital transactions with affiliates ............... -- -- (30,369) --
----------- ----------- ----------- -----------
Net cash provided by (used in) continuing
operations ........................................ (543,337) (191,312) 2,090,967 1,844
Net cash provided by (used in) discontinued
operations ........................................ -- (13,869) 70,314 21,693
----------- ----------- ----------- -----------
Net cash provided by (used in) financing
activities ........................................ (543,337) (205,181) 2,161,281 23,537
Effect of exchange rate changes on cash and cash equivalents .... -- (806) 111 (292)
----------- ----------- ----------- -----------
Net increase (decrease) in cash and cash equivalents ............ (2,895) (128,460) 194,078 (26,462)
Cash and cash equivalents at beginning of period ................ 65,618 194,078 -- 96,821
----------- ----------- ----------- -----------
Cash and cash equivalents at end of period ...................... $ 62,723 $ 65,618 $ 194,078 $ 70,359
=========== =========== =========== ===========
See accompanying notes to financial statements.
46
47
PEABODY ENERGY CORPORATION
STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY/INVESTED CAPITAL
(DOLLARS IN THOUSANDS, EXCEPT SHARE DATA)
SHARES ADDITIONAL
------------------------------------ PREFERRED COMMON PAID-IN
PREDECESSOR COMPANY PREFERRED CLASS A CLASS B STOCK STOCK CAPITAL
------------------- ---------- ------- -------- --------- ------ ----------
March 31, 1998 ........................................ -- -- -- $ -- $ -- $ --
Comprehensive loss:
Net income ........................................ -- -- -- -- -- --
Foreign currency translation adjustment ........... -- -- -- -- -- --
Comprehensive loss ..................................
Dividend paid ....................................... -- -- -- -- -- --
Net transactions with affiliates .................... -- -- -- -- -- --
---------- ---------- ---------- ----- ---------- ----------
May 19, 1998 .......................................... -- -- -- $ -- $ -- $ --
========== ========== ========== ===== ========== ==========
May 20, 1998 .......................................... -- -- -- $ -- $ -- $ --
Capital contribution ................................ 7,000,000 26,600,000 -- 50 190 479,760
Comprehensive income:
Net income ........................................ -- -- -- -- -- --
Foreign currency translation adjustment ........... -- -- -- -- -- --
Minimum pension liability (net of $1,248 tax
provision) ...................................... -- -- -- -- -- --
Comprehensive income ................................
Stock grants to employees ........................... -- -- 775,778 -- 5 13,119
Stock purchases by employees ........................ -- -- 216,499 -- 2 1,093
---------- ---------- ---------- ----- ---------- ----------
March 31, 1999 ........................................ 7,000,000 26,600,000 992,277 50 197 493,972
Comprehensive income:
Net income ........................................ -- -- -- -- -- --
Foreign currency translation adjustment ........... -- -- -- -- -- --
Minimum pension liability (net of $1,248 tax
benefit) ........................................ -- -- -- -- -- --
Comprehensive income ................................
Stock grants to employees ........................... -- -- 46,899 -- -- 265
Loan repayments ..................................... -- -- -- -- -- --
Additional loans .................................... -- -- -- -- -- --
Shares repurchased .................................. -- -- (80,913) -- -- --
---------- ---------- ---------- ----- ---------- ----------
March 31, 2000 ........................................ 7,000,000 26,600,000 958,263 50 197 494,237
Comprehensive income:
Net income ........................................ -- -- -- -- -- --
Foreign currency translation adjustment ........... -- -- -- -- -- --
Reclassification of foreign currency translation -- -- -- -- --
adjustment ......................................
Minimum pension liability (net of $615 tax
benefit) ........................................ -- -- -- -- -- --
Comprehensive income ................................
Stock grants to employees ........................... -- -- 284,362 -- 1 3,961
Loan repayments ..................................... -- -- -- -- -- --
Shares repurchased .................................. -- -- (232,116) -- -- --
---------- ---------- ---------- ----- ---------- ----------
March 31, 2001 ........................................ 7,000,000 26,600,000 1,010,509 $ 50 $ 198 $ 498,198
========== ========== ========== ===== ========== ==========
ACCUMULATED
OTHER TOTAL
COMPRE- STOCKHOLDERS'
EMPLOYEE HENSIVE EQUITY/
STOCK INCOME RETAINED INVESTED TREASURY INVESTED
LOANS (LOSS) EARNINGS CAPITAL STOCK CAPITAL
----------- --------- ----------- ------------ ----------- -----------
March 31, 1998 .................................... $ -- $ (42,184) $ -- $ 1,730,026 $ -- $ 1,687,842
Comprehensive loss:
Net income .................................... -- -- -- 476 -- 476
Foreign currency translation adjustment ....... -- (17,974) -- -- -- (17,974)
-----------
Comprehensive loss .............................. (17,498)
Dividend paid ................................... -- -- -- (173,330) -- (173,330)
Net transactions with affiliates ................ -- -- -- 360 -- 360
----------- ----------- ----------- ------------ ----------- -----------
May 19, 1998 ...................................... $ -- $ (60,158) $ -- $ 1,557,532 $ -- $ 1,497,374
=========== =========== =========== ============ =========== ===========
May 20, 1998 ...................................... $ -- $ -- $ -- $ -- $ -- $ --
Capital contribution ............................ -- -- -- -- -- 480,000
Comprehensive income:
Net income .................................... -- -- 1,009 -- -- 1,009
Foreign currency translation adjustment ....... -- 4,128 -- -- -- 4,128
Minimum pension liability (net of $1,248 tax... -- (1,795) -- -- -- (1,795)
provision) .................................. -----------
Comprehensive income ............................ 3,342
Stock grants to employees ....................... (1,236) -- -- -- -- 11,888
Stock purchases by employees .................... (1,095) -- -- -- -- --
----------- ----------- ----------- ------------ ----------- -----------
March 31, 1999 .................................... (2,331) 2,333 1,009 -- -- 495,230
Comprehensive income:
Net income .................................... -- -- 28,210 -- -- 28,210
Foreign currency translation adjustment ....... -- (16,795) -- -- -- (16,795)
Minimum pension liability (net of $1,248 tax... -- 1,795 -- -- -- 1,795
benefit) .................................... -----------
Comprehensive income ............................ 13,210
Stock grants to employees ....................... (103) -- -- -- -- 162
Loan repayments ................................. 901 -- -- -- -- 901
Additional loans ................................ (858) -- -- -- -- (858)
Shares repurchased .............................. -- -- -- -- (219) (219)
----------- ----------- ----------- ------------ ----------- -----------
March 31, 2000 .................................... (2,391) (12,667) 29,219 -- (219) 508,426
Comprehensive income:
Net income .................................... -- -- 107,060 -- -- 107,060
Foreign currency translation adjustment ....... -- (26,144) -- -- -- (26,144)
Reclassification of foreign currency translation
adjustment .................................. -- 38,811 -- -- -- 38,811
Minimum pension liability (net of $615 tax .... -- (862) -- -- -- (862)
benefit) .................................... -----------
Comprehensive income ............................ 118,865
Stock grants to employees ....................... (705) -- -- -- 1,260 4,517
Loan repayments ................................. 543 -- -- -- -- 543
Shares repurchased .............................. -- -- -- -- (1,113) (1,113)
----------- ----------- ----------- ------------ ----------- -----------
March 31, 2001 .................................... $ (2,553) $ (862) $ 136,279 $ -- $ (72) $ 631,238
=========== =========== =========== ============ =========== ===========
See accompanying notes to financial statements.
47
48
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS
(DOLLARS IN THOUSANDS, EXCEPT WHERE NOTED AND PER SHARE DATA)
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The consolidated financial statements include the consolidated balance
sheets of Peabody Energy Corporation (the "Company" or "Peabody") as of March
31, 2001 and 2000, and the consolidated results of operations and cash flows for
the years ended March 31, 2001 and 2000 and the period from May 20, 1998 to
March 31, 1999 (hereafter referred to as the "period ended March 31, 1999").
These financial statements include the subsidiaries (collectively, known as the
"Predecessor Company" or "P&L Coal Group") of Peabody Holding Company, Inc.
("Peabody Holding Company"), Gold Fields Mining Corporation ("Gold Fields")
which owns Lee Ranch Coal Company ("Lee Ranch"), Citizens Power LLC ("Citizens
Power") and Peabody Resources Limited ("Peabody Resources"), an Australian
company. The combined financial statements include the combined results of
operations and cash flows of the Predecessor Company from April 1, 1998 to May
19, 1998 (hereafter referred to as the "period ended May 19, 1998"). P&L Coal
Holdings Corporation, a holding company that was formed by Lehman Brothers
Merchant Banking Partners II L.P. ("Lehman Brothers Merchant Banking") on
February 27, 1998, acquired P&L Coal Group from The Energy Group PLC effective
May 20, 1998. Lehman Brothers Merchant Banking is an investment fund affiliated
with Lehman Brothers Inc.
In May 2000, the Company signed a purchase and sale agreement with Edison
Mission Energy to sell Citizens Power (see Note 4). Results of operations and
cash flows for all periods presented reflect Citizens Power as a discontinued
operation. In January 2001, the Company sold its Australian operations (see Note
3).
On April 10, 2001, the Company changed its name from P&L Coal Holdings
Corporation to Peabody Energy Corporation.
Stock Split
On May 17, 2001, the Company effected a 1.4-for-one stock split of its
preferred and common stock. All references to number of shares, per share
amounts and stock option data have been restated to reflect the stock split.
Description of Business
The Company is principally engaged in the mining of coal for sale primarily
to electric utilities. The Company also markets and trades coal and emission
allowances.
New Pronouncements
Effective April 1, 1998, the Company adopted Statement of Financial
Accounting Standards (SFAS) No. 130, "Reporting Comprehensive Income." SFAS No.
130 requires that noncash changes in stockholders' equity be combined with net
income and reported in a new financial statement category entitled "accumulated
other comprehensive income."
The Company also adopted SFAS No. 131, "Disclosures About Segments of an
Enterprise and Related Information" and SFAS No. 132, "Employers' Disclosures
About Pensions and Other Postretirement Benefits" effective April 1, 1998. SFAS
No. 131 and SFAS No. 132, address the disclosures required for the Company's
operating segments and employee benefit obligations, respectively.
The adoption of SFAS Nos. 130, 131 and 132 had no effect on the Company's
financial condition or results of operations.
48
49
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
In June 1998, the Financial Accounting Standards Board issued SFAS No. 133,
"Accounting for Derivative Instruments and Hedging Activities." SFAS No. 133 (as
amended by SFAS Nos. 137 and 138) requires the recognition of all derivatives as
assets or liabilities within the balance sheet and requires both the derivatives
and the underlying exposure to be recorded at fair value. Any gain or loss
resulting from changes in fair value will be recorded as part of the results of
operations, or as a component of comprehensive income or loss, depending upon
the intended use of the derivative. The effective date of SFAS No. 133 is fiscal
years beginning after June 15, 2000 (effective April 1, 2001 for the Company).
The Company does not anticipate that the adoption of SFAS No. 133 will have a
material effect on its financial condition or results of operations, subject to
new or revised implementation guidelines issued by the Derivatives
Implementation Group.
Joint Ventures
Joint ventures are accounted for using the equity method except for
undivided interests in Australia, which, prior to its sale in January 2001, was
reported using pro rata consolidation whereby the Company reported its
proportionate share of assets, liabilities, income and expenses. All significant
intercompany transactions have been eliminated in consolidation.
The financial statements include the following asset and operating amounts
for Australian entities utilizing pro rata consolidation (dollars in thousands):
PREDECESSOR
COMPANY
--------------
YEAR ENDED YEAR ENDED PERIOD ENDED PERIOD ENDED
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- -------------- --------------
Total revenue...................................... $ 144,481 $ 122,689 $ 72,057 $ 10,996
Operating profit................................... 21,111 17,038 18,767 3,695
Total assets (at period end)....................... -- 149,864 -- --
Accounting for Coal and Emission Allowance Trading
The Company engages in risk management activities for both trading and
non-trading purposes. Activities for trading purposes, generally consisting of
coal and emission allowance trading, are accounted for using the fair value
method. Under such method, the derivative commodity instruments (forwards,
options and swaps) with third parties are reflected at market value and are
included in "Assets and liabilities from coal and emission allowance trading
activities" in the consolidated balance sheets. In the absence of quoted values,
financial commodity instruments are valued at fair value, considering the net
present value of the underlying sales and purchase obligations, volatility of
the underlying commodity, appropriate reserves for market and credit risks and
other factors, as determined by management. Subsequent changes in market value
are recognized as gains or losses in "Other revenues" in the period of change.
As a writer of options, the Company receives a premium when the option is
written and then bears the risk of unfavorable changes in the price of the
financial instruments underlying the option. Forwards, swaps and
over-the-counter options are traded in unregulated markets.
Over-the-counter forwards, options and swaps are either liquidated with the
same counterparty or held to settlement date. For these financial instruments,
the unrealized gains or losses on financial settlements, rather than the
contract amounts, represent the approximate future cash requirements. Realized
gains and losses on trading activities are recorded as part of "Other revenues"
as they occur. Physical settlements are recorded on a gross basis within "Sales"
and "Operating costs and expenses."
49
50
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Derivative Financial Instruments
A portion of the Company's long-term indebtedness bears interest at rates
that fluctuate based upon certain indices. The Company utilizes financial
instruments, such as interest rate swap agreements, to mitigate the impact of
changes in interest rates on a portion of its floating rate debt. Gains or
losses on interest rate swap agreements are recognized as they occur and are
included as a component of interest expense.
Prior to the sale in January 2001, the Company's Australian operations used
forward currency contracts to manage their exposure against foreign currency
fluctuations on sales denominated in U.S. dollars. These financial instruments
were accounted for using the deferral method. Changes in the market value of
these transactions were deferred until the gain or loss on the underlying hedged
item was recognized as part of the related transaction. If the future sale was
no longer anticipated, the changes in market value of the forward currency
contracts were recognized as an adjustment to revenue in the period of change.
Revenue Recognition
The Company incurs certain "add-on" taxes and fees on coal sales. Coal
sales are reported including taxes and fees charged by various federal and state
governmental bodies. The Company recognizes revenue from coal sales when title
passes to the customer.
Other Revenues
Other revenues include royalties related to coal lease agreements, earnings
and losses from joint ventures, management fees, farm income, contract
restructuring payments, coalbed methane extraction, coal and emission allowance
trading activities and revenues from contract mining services. Royalty income
generally results from the lease or sub-lease of mineral rights to third
parties, with payments based upon a percentage of the selling price or an amount
per ton of coal produced. Certain agreements require minimum annual lease
payments regardless of the extent to which minerals are produced from the
leasehold. The terms of these agreements generally range from specified periods
of five to 20 years, or can be for an unspecified period until all reserves are
depleted.
Revenues from coal trading activities are recognized for the differences
between contract and market prices.
Cash and Cash Equivalents
Cash and cash equivalents are stated at cost, which approximates fair
value. Cash equivalents consist of highly liquid investments with original
maturities of three months or less.
Inventories
Materials and supplies and coal inventory are valued at the lower of
average cost or market. Coal inventory costs include labor, supplies, equipment
costs, operating overhead and other related costs.
Property, Plant, Equipment and Mine Development
Property, plant, equipment and mine development are recorded at cost.
Interest costs applicable to major asset additions are capitalized during the
construction period, including $0.3 million and $1.8 million for the years ended
March 31, 2001 and 2000, respectively, and $3.0 million and $0.2 million for the
periods ended March 31, 1999 and May 19, 1998, respectively.
50
51
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Expenditures which extend the useful lives of existing plant and equipment
are capitalized. Maintenance and repairs are charged to operating costs as
incurred. Costs incurred to develop coal mines or to expand the capacity of
operating mines are capitalized. Costs incurred to maintain current production
capacity at a mine and exploration expenditures are charged to operating costs
as incurred. Certain costs to acquire computer hardware and the development
and/or purchase of software for internal use are capitalized and depreciated
over the estimated useful lives.
The fair value of coal reserves was established by an independent third
party review and evaluation at the time of the Company's acquisition in May
1998. Reserves acquired subsequent to that date are recorded at cost. At March
31, 2001, the net book value of coal reserves totaled $3.5 billion. This amount
includes $1.3 billion attributable to properties where the Company is not
currently engaged in mining operations or leasing to third parties and,
therefore, the coal reserves are not currently being depleted.
Depletion of coal interests is computed using the units-of-production
method utilizing only proven and probable reserves in the depletion base. Mine
development costs are principally amortized over the estimated lives of the
mines using the straight-line method. Depreciation of plant and equipment
(excluding life of mine assets) is computed using the straight-line method over
the estimated useful lives as follows:
YEARS
----------------
Building and improvements................................................... 10 to 20
Machinery and equipment..................................................... 2 to 30
Leasehold improvements...................................................... Life of Lease
In addition, certain plant and equipment assets associated with mining are
depreciated using the straight-line method over the estimated life of the mine,
which varies from three to 24 years.
Accrued Reclamation and Other Environmental Liabilities
The Company records a liability for the estimated costs to reclaim land as
the acreage is disturbed during the ongoing surface mining process. The
estimated costs to reclaim support acreage and to perform other related
functions at both surface and underground mines are recorded ratably over the
lives of the mines. As of March 31, 2001, the Company had $651.8 million in
surety bonds outstanding to secure reclamation obligations or activities. The
amount of reclamation self-bonding in certain states in which the Company
qualifies was $216.5 million as of March 31, 2001.
Accruals for other environmental matters are recorded in operating expenses
when it is probable that a liability has been incurred and the amount of the
liability can be reasonably estimated. Accrued liabilities are exclusive of
claims against third parties and are not discounted. In general, costs related
to environmental remediation are charged to expense.
Income Taxes
Income taxes are accounted for using a balance sheet approach known as the
liability method. The liability method accounts for deferred income taxes by
applying statutory tax rates in effect at the date of the balance sheet to
differences between the book and tax basis of assets and liabilities.
Postemployment Benefits
The Company provides postemployment benefits to qualifying employees,
former employees and dependents under the provisions of various benefit plans or
as required by state or federal law. The Company accounts for workers'
compensation obligations and other Company-provided postemployment benefits on
the accrual basis of accounting.
51
52
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Earnings Per Share
The Company has two classes of common stock and, as such, applies the
"two-class method" of computing earnings per share as prescribed in SFAS No.
128, "Earnings Per Share." In accordance with SFAS No. 128, income or loss is
allocated to preferred stock, Class A common stock and Class B common stock on a
pro-rata basis.
Basic earnings (loss) per share is calculated by dividing income (loss)
from continuing operations, income (loss) from discontinued operations,
extraordinary loss from early extinguishment of debt and net income,
respectively, that is attributed to the Company's Class A and Class B common
shares by the weighted average number of common shares outstanding for each
class of common stock for each respective period. Diluted earnings (loss) per
share is calculated by dividing income from continuing operations, income (loss)
from discontinued operations, extraordinary loss from early extinguishment of
debt and net income, respectively, that is attributed to the Company's Class A
and Class B common shares by the weighted average number of common and common
equivalent shares outstanding for each class of common stock for each respective
period. Any potential difference between basic and diluted earnings (loss) per
share is solely attributable to stock options. For the years ended March 31,
2001 and 2000 and the period ended March 31, 1999 all options (for 5.2 million
shares, 5.2 million shares and 5.3 million shares, respectively) were excluded
from the diluted earnings per share calculations for the Company's Class A and
Class B common stock because they were anti-dilutive. A reconciliation of income
(loss) from continuing operations, income (loss) from discontinued operations,
extraordinary loss from early extinguishment of debt and net income follows:
YEAR ENDED YEAR ENDED MAY 20, 1998
MARCH 31, MARCH 31, TO MARCH 31,
2001 2000 1999
------------ ------------ ------------
(Dollars in thousands)
Income (loss) from continuing operations attributed to:
Preferred stock .................................................. $ 20,819 $ 23,998 $ (1,124)
Class A common stock ............................................. 79,111 91,190 (4,273)
Class B common stock ............................................. 2,750 3,382 (36)
------------ ------------ ------------
$ 102,680 $ 118,570 $ (5,433)
============ ============ ============
Income (loss) from discontinued operations attributed to:
Preferred stock .................................................. $ 2,621 $ (18,289) $ 1,333
Class A common stock ............................................. 9,958 (69,494) 5,067
Class B common stock ............................................. 346 (2,577) 42
------------ ------------ ------------
$ 12,925 $ (90,360) $ 6,442
============ ============ ============
Extraordinary loss from early extinguishment of debt attributed to:
Preferred stock .................................................. $ (1,733) $ -- $ --
Class A common stock ............................................. (6,583) -- --
Class B common stock ............................................. (229) -- --
------------ ------------ ------------
$ (8,545) $ -- $ --
============ ============ ============
Net income attributed to:
Preferred stock .................................................. $ 21,707 $ 5,709 $ 209
Class A common stock ............................................. 82,486 21,696 793
Class B common stock ............................................. 2,867 805 7
------------ ------------ ------------
$ 107,060 $ 28,210 $ 1,009
============ ============ ============
Weighted average shares outstanding:
Class A common stock ............................................. 26,600,000 26,600,000 26,600,000
Class B common stock ............................................. 924,626 986,370 223,383
------------ ------------ ------------
27,524,626 27,586,370 26,823,383
============ ============ ============
52
53
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Concentration of Credit Risk and Market Risk
The Company's power, coal and emission allowance trading and risk
management activities give rise to market risk, which represents the potential
loss caused by a change in the market value of a particular commitment. Market
risks are actively monitored to ensure compliance with the risk management
policies of the Company. Policies are in place that limit the Company's total
net exposure at any point in time. Procedures exist which allow for monitoring
of all commitments and positions, with daily reporting to senior management.
The Company's concentration of credit risk is substantially with energy
producers and marketers and electric utilities. The Company's policy is to
independently evaluate each customer's creditworthiness prior to entering into
transactions and to constantly monitor the credit extended. In the event that
the Company engages in a transaction with a counterparty that does not meet its
credit standards, the Company will protect its position by requiring the
counterparty to provide appropriate credit enhancement. Counterparty risk with
respect to interest rate swap transactions is not considered to be significant
based upon the creditworthiness of the participating financial institutions.
Approximately 37% of the Company's U.S. coal employees are affiliated with
organized labor unions, which accounts for approximately 23% of sales volume in
the U.S. during fiscal year 2001. Hourly workers at the Company's mines in
Arizona, Colorado and Montana are represented by the United Mine Workers' of
America under the Western Surface Agreement, which was ratified in 2000 and is
effective through September 1, 2005. Union labor east of the Mississippi is also
represented by the United Mine Workers of America but is subject to the National
Bituminous Coal Wage Agreement. On December 16, 1997, this five-year labor
agreement effective from January 1, 1998 to December 31, 2002, was ratified by
the United Mine Workers of America.
Use of Estimates in the Preparation of the Financial Statements
The preparation of financial statements in conformity with 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 reported amounts of revenues and expenses during the reporting
period. Actual results could differ from those estimates.
Impairment of Long-Lived Assets
The Company records impairment losses on long-lived assets used in
operations when events and circumstances indicate that the assets might be
impaired and the undiscounted cash flows estimated to be generated by those
assets under various assumptions are less than the carrying amounts of those
assets. Impairment losses are measured by comparing the estimated fair value of
the assets to their carrying amount.
Foreign Currency Translation
Assets and liabilities of foreign affiliates are generally translated at
current exchange rates, and related translation adjustments are reported as a
component of comprehensive income. Income statement accounts are translated at
an average rate for each period. The Company sold its Australian mining
operations in January 2001.
Reclassifications
Certain amounts in prior periods have been reclassified to conform with the
report classifications of the year ended March 31, 2001, with no effect on
previously reported net income or stockholders' equity.
53
54
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(2) BUSINESS COMBINATIONS
Black Beauty Coal Company
Effective January 1, 1999, the Company purchased an additional 38.3%
interest in Black Beauty Coal Company ("Black Beauty"), raising its ownership
percentage to 81.7%. Total consideration paid for the additional interest was
$150.7 million. The acquisition was accounted for as a purchase and,
accordingly, the operating results of Black Beauty have been included in the
Company's financial statements since the effective date of acquisition. Prior to
the acquisition, the Company accounted for its ownership using the equity method
of accounting.
Effective January 1, 2000, Black Beauty invested $6.6 million to increase
its ownership interest and obtain control of three of its Midwestern coal mining
affiliates--Sugar Camp Coal, LLC, Arclar Coal Company, LLC and United Minerals
Company, LLC. Prior to fiscal year 2000, interests in these affiliates were
accounted for under the equity method, and effective January 1, 2000, the
Company obtained decision-making control and began accounting for its 75%
interest in the affiliates on a consolidated basis. The Company has elected to
consolidate these affiliates as part of Black Beauty's results of operations
effective April 1, 1999.
Peabody Resources
Effective August 20, 1999, Peabody Resources purchased a 55% interest in
the Moura Mine in Queensland, Australia for $30.2 million. The acquisition was
accounted for as a purchase and the operating results were included in the
Company's financial statements since the date of acquisition using pro rata
consolidation. The Moura Mine was included in the sale of the Australian
operations in January 2001.
P&L Coal Group
Effective May 20, 1998, the Company paid The Energy Group PLC $2,003.5
million in cash for P&L Coal Group. The acquisition was financed by a $480.0
million equity contribution by Lehman Brothers Merchant Banking and affiliates
and borrowings of $1,523.5 million.
The acquisition has been accounted for under the purchase method of
accounting. Historical assets received of $6,406.6 million were increased to a
fair value of $7,252.4 million. Historical liabilities assumed of $4,909.2
million were increased to a fair value of $5,248.9 million. Fair value
adjustments to liabilities consist primarily of recognition of restructuring
liabilities that are discussed in Note 15, an increase in the fair value of
long-term debt assumed, the elimination of actuarial gains, losses and
deferrals, adjustments to conform foreign entities to U.S. generally accepted
accounting principles and the deferred income tax effects of purchase
accounting. The fair value of liabilities assumed included an estimated $75.0
million of transaction fees.
54
55
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Below are the balance sheet of Peabody Energy Corporation (including the
effect of acquisition financing), the Company's historical balance sheet at May
19, 1998, purchase accounting adjustments and the opening balance sheet.
ACQUISITION OF
ACQUISITION PREDECESSOR
FINANCING & CO. AND
FORMATION OF PREDECESSOR PURCHASE
PEABODY ENERGY COMPANY ACCOUNTING
CORPORATION HISTORICAL ADJUSTMENTS MAY 19, 1998
-------------- ----------- --------------- ------------
ASSETS
Cash related to acquisition/financing ................. $ 2,297,390 $ -- $(2,297,390) $ --
Other current assets .................................. -- 2,151,059 285,376 2,436,435
Property, plant, equipment and mine development,
net ................................................ -- 3,642,551 746,961 4,389,512
Investments and other assets .......................... 75,000 612,977 32,334 720,311
----------- ----------- ----------- -----------
Total assets ..................................... $ 2,372,390 $ 6,406,587 $(1,232,719) $ 7,546,258
=========== =========== =========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current maturities of long-term debt .................. $ 16,500 $ 73,681 $ -- $ 90,181
Other current liabilities ............................. 75,000 1,764,343 19,868 1,859,211
Long-term debt, less current maturities ............... 1,800,890 -- -- 1,800,890
Other long-term debt .................................. -- 559,881 33,779 593,660
Deferred income taxes ................................. -- 662,064 93,940 756,004
Other noncurrent liabilities .......................... -- 1,849,244 117,068 1,966,312
----------- ----------- ----------- -----------
Total liabilities ................................ 1,892,390 4,909,213 264,655 7,066,258
Invested capital ...................................... -- 1,497,374 (1,497,374) --
Stockholders' equity .................................. 480,000 -- -- 480,000
----------- ----------- ----------- -----------
Total liabilities & stockholders' equity ......... $ 2,372,390 $ 6,406,587 $(1,232,719) $ 7,546,258
=========== =========== =========== ===========
The Company finalized its purchase price allocation at March 31, 1999 based
upon the receipt of all the information it had arranged to obtain in order to
complete its estimates. This included independent appraisals on property, plant,
equipment and mine development (including land and coal interests) and actuarial
valuations supporting final adjustments to its employee-related liabilities. In
addition, agreement on the final purchase price was reached with The Energy
Group PLC.
The following unaudited pro forma results of operations assumed the
acquisitions had occurred as of April 1, 1998:
2000 1999
----------- -----------
(Dollars in thousands)
Total revenues.................................................................. $ 2,728,694 $ 2,765,979
Loss before income taxes, minority interests, discontinued operations and
extraordinary loss........................................................... (6,278) (1,464)
Net income (loss)............................................................... 28,916 (8,964)
(3) SALE OF AUSTRALIAN OPERATIONS
On January 29, 2001, the Company sold its Australian operations to Coal &
Allied, a 71%-owned subsidiary of Rio Tinto Limited. The selling price was
$446.8 million, plus the assumption of all liabilities. The selling price
represents the $455.0 million original contract price at January 29, 2001 less
an $8.2 million purchase price adjustment. The Company used the proceeds from
the sale to repay long-term debt.
The pretax gain on sale of $171.7 million is included in the statement of
operations for the year ended March 31, 2001. The gain on sale was $124.2
million on an after-tax basis.
55
56
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(4) DISCONTINUED OPERATIONS
On March 13, 2000 the Board of Directors authorized management to sell
Citizens Power, its wholly-owned subsidiary that engaged in power trading and
power contract restructuring transactions. Subsequent to March 31, 2000, the
Company signed an agreement to sell Citizens Power to Edison Mission Energy. As
of March 31, 2000, the Company estimated its loss on disposal of the entity to
be $109.5 million on a pretax basis ($78.3 million after-tax), which included an
$8.0 million pretax provision for expected operating losses through the expected
disposal date. The Company completed the sale of operations and the monetization
of non-trading assets held by Citizens Power in March 2001, resulting in an
after-tax decrease to the loss on disposal of $12.9 million.
As a result of the estimated loss on the disposal of the entity, the
results of operations of Citizens Power were reported separately as a
discontinued operation in the statements of operations for all periods
presented, and are summarized as follows (dollars in thousands):
PREDECESSOR
COMPANY
-----------------
YEAR ENDED MAY 20, 1998 TO APRIL 1, 1998 TO
MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- --------------- -----------------
Revenues............................................................. $ 17,225 $37,394 $ 1,750
Income (loss) before income taxes.................................... (13,384) 12,477 (1,953)
Income tax provision (benefit)....................................... (1,297) 6,035 (189)
Income (loss) from discontinued operations........................... (12,087) 6,442 (1,764)
The fair value of net assets related to the discontinued operation were
segregated in the March 31, 2000 consolidated balance sheet and include the
following (dollars in thousands):
Cash............................................................................................ $ 41,222
Accounts receivable............................................................................. 46,339
Assets from power trading activities............................................................ 908,256
Liabilities from power trading.................................................................. (524,366)
Other current liabilities....................................................................... (75,701)
Non-recourse debt............................................................................... (305,750)
----------
$ 90,000
==========
(5) ACCOUNTS RECEIVABLE SECURITIZATION
In March 2000, the Company and its wholly-owned, bankruptcy-remote
subsidiary ("Seller") established a five-year accounts receivable securitization
program. Under the program, undivided interests in a pool of eligible trade
receivables that have been contributed to the Seller are sold, without recourse,
to a multi-seller, asset backed commercial paper conduit ("Conduit"). Purchases
by the Conduit are financed with the sale of highly rated commercial paper. The
Company utilized proceeds from the sale of its accounts receivable to repay
long-term debt, effectively reducing its overall borrowing costs. The funding
cost of the securitization program for fiscal year 2001 was $8.7 million.
Under the provisions of SFAS No. 125, "Accounting for Transfers and
Servicing of Financial Assets and Extinguishments of Liabilities," (as amended
by SFAS No. 140) the securitization transactions have been recorded as sales,
with those accounts receivable sold to the Conduit removed from the consolidated
balance sheet. The amount of undivided interests in accounts receivable sold to
the Conduit were $140.0 and $100.0 million at March 31, 2001 and March 31, 2000,
respectively.
56
57
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The Seller is a separate legal entity from the Company. The Seller's assets
are available first and foremost to satisfy the claims of its creditors.
Eligible receivables, as defined in the securitization agreement, consist of
trade receivables from our domestic subsidiaries, excluding Black Beauty,
reduced for certain items, including past due balances and concentration limits.
Of the eligible pool of receivables contributed to the Seller, undivided
interests in only a portion of the pool are sold to the Conduit. The portion of
eligible receivables not sold to the Conduit remain an asset of the Seller
($50.9 million as of March 31, 2001). The Seller's interest in these receivables
is subordinate to the Conduit's interest in the event of default under the
securitization agreement.
(6) COAL INVENTORY
Coal inventory consisted of the following as of March 31:
2001 2000
--------- ---------
(Dollars in thousands)
Saleable coal..................................................... $ 34,193 $ 41,047
Raw coal.......................................................... 14,587 18,400
Work in process................................................... 122,699 133,894
--------- ---------
$ 171,479 $ 193,341
========= =========
Raw coal represents coal stockpiles that may be sold in current condition
or may be further processed prior to shipment to a customer. Work in process
consists of the costs to remove overburden above an unmined coal seam as part of
the surface mining process. These costs include labor, supplies, equipment costs
and operating overhead, and are charged to operations as coal from the seam is
sold.
(7) LEASES
The Company leases equipment and facilities under various noncancelable
lease agreements. Certain lease agreements require the maintenance of specified
ratios and contain restrictive covenants which limit indebtedness, subsidiary
dividends, investments, asset sales and other Company actions. Rental expense
under operating leases was $60.4 million and $55.7 million for the years ended
March 31, 2001 and 2000, respectively, and $34.6 million and $5.4 million for
the periods ended March 31, 1999 and May 19, 1998, respectively. The net book
value of property, plant, equipment and mine development assets under capital
leases was $2.2 million and $24.9 million at March 31, 2001 and 2000,
respectively.
The Company also leases coal reserves under agreements that require
royalties to be paid as the coal is mined. Certain agreements also require
minimum annual royalties to be paid regardless of the amount of coal mined
during the year. Total royalty expense was $163.9 million and $164.2 million for
the years ended March 31, 2001 and 2000, respectively and $123.2 million and
$17.3 million for the periods ended March 31, 1999 and May 19, 1998,
respectively.
A substantial amount of the coal mined by the Company is produced from
reserves leased from the owner of the coal. One of the major lessors is the U.S.
government, from which the Company leases substantially all of the coal it mines
in Wyoming, Montana and Colorado under terms set by Congress and administered by
the U.S. Bureau of Land Management. The terms of these leases are generally for
an initial term of ten years but may be extended by diligent development and
mining of the reserve until all economically recoverable reserves are depleted.
The Company has met the diligent development requirements for substantially all
of these federal leases either directly through production or by including the
lease as a part of a logical mining unit with other leases upon which
development has occurred. Annual production on these federal leases must total
at least 1% of the original amount of coal in the entire logical mining unit.
Royalties are payable monthly at a rate of 12.5% of the gross realization from
the sale of the coal mined using surface mining methods and at a rate of 8.0% of
the gross realization for coal produced using underground mining methods. The
Company also leases the coal production at its Arizona mines from The Navajo
Nation and the Hopi Tribe under leases that are administered by the U.S.
Department of the Interior. These leases expire once mining activities cease.
The royalty rates are also generally based upon a percentage of the gross
realization from the sale of coal. These rates are subject to redetermination
every ten years under the terms of the leases. The remainder of the leased coal
is
57
58
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
generally leased from state governments, land holding companies and various
individuals. The duration of these leases varies greatly. Typically, the lease
terms are automatically extended as long as active mining continues. Royalty
payments are generally based upon a specified rate per ton or a percentage of
the gross realization from the sale of the coal.
In fiscal years 2001 and 2000, the Company sold certain assets for $28.8
million and $34.2 million, respectively, and those assets were leased back under
operating lease agreements from the purchasers over a period of seven to 13
years. No gains were recognized on these transactions. Each lease agreement
contains renewal options at lease termination and purchase options at amounts
approximating fair market value during the lease and at lease termination.
Future minimum lease and royalty payments as of March 31, 2001 are as
follows:
CAPITAL OPERATING COAL
FISCAL YEAR ENDING MARCH 31 LEASES LEASES RESERVES
--------------------------- ------- --------- ---------
(Dollars in thousands)
2002................................................................................ $ 802 $ 59,211 $ 39,114
2003................................................................................ 493 52,675 36,504
2004................................................................................ 371 48,428 14,243
2005................................................................................ 363 42,645 14,061
2006................................................................................ 470 37,845 11,738
2007 and thereafter................................................................. 53 68,836 37,612
------- --------- ---------
Total minimum lease payments........................................................ 2,552 $ 309,640 $ 153,272
========= =========
Less interest....................................................................... 397
-------
Present value of minimum capital lease payments..................................... $ 2,155
=======
(8) ACCOUNTS PAYABLE AND ACCRUED EXPENSES
Accounts payable and accrued expenses consisted of the following as of
March 31:
2001 2000
--------- ---------
(Dollars in thousands)
Trade accounts payable........................................................................ $ 208,174 $ 180,682
Accrued taxes other than income............................................................... 78,342 76,841
Accrued payroll and related benefits.......................................................... 48,224 85,281
Accrued health care........................................................................... 66,407 62,127
Accrued interest.............................................................................. 38,170 46,166
Workers' compensation obligations............................................................. 33,568 35,246
Accrued royalties............................................................................. 21,445 18,624
Accrued lease payments........................................................................ 10,296 11,188
Other accrued expenses........................................................................ 71,850 56,982
--------- ---------
Total accounts payable and accrued expenses.............................................. $ 576,476 $ 573,137
========= =========
58
59
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(9) INCOME TAXES
Pretax income (loss) from continuing operations consisted of the following
(dollars in thousands):
PREDECESSOR
COMPANY
-----------------
MAY 20, 1998 APRIL 1, 1998
YEAR ENDED YEAR ENDED TO TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- -------------- -----------------
Pretax income (loss) from continuing operations:
United States......................................... $ 105,184 $ (49,550) $ (32,142) $ 4,134
Non U.S............................................... 47,710 42,152 31,608 2,636
--------- --------- --------- -------
$ 152,894 $ (7,398) $ (534) $ 6,770
========= ========= ========= =======
Total income tax provision (benefit) from continuing operations consisted
of the following (dollars in thousands):
PREDECESSOR
COMPANY
------------------
MAY 20, 1998 APRIL 1, 1998
YEAR ENDED YEAR ENDED TO TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- -------------- ------------------
Current:
U.S. federal....................................... $ 170 $ -- $ -- $ --
Non U.S............................................ 19,150 16,224 9,700 1,427
State.............................................. 100 57 26 79
-------- ---------- ------- -------
Total current................................. 19,420 16,281 9,726 1,506
-------- ---------- ------- -------
Deferred:
U.S. federal....................................... 29,284 (124,807) (8,309) 1,904
Non U.S............................................ (1,039) (4,037) 2,026 --
State.............................................. (4,975) (28,959) (431) 1,120
-------- ---------- ------- -------
Total deferred................................ 23,270 (157,803) (6,714) 3,024
-------- ---------- ------- -------
Total provision (benefit)..................... $ 42,690 $ (141,522) $ 3,012 $ 4,530
======== ========== ======= =======
The deferred tax benefit for the year ended March 31, 2000 includes the
effect of a change in tax regulations and statutes in that current period which
allowed the Company to make a tax election to treat a wholly-owned partnership
as a corporation. The election eliminated a $144.0 million deferred tax
liability previously recognized pursuant to the provisions of SFAS No. 109 on
the "outside tax basis," which represents the tax effected difference between
the book value and the tax basis of the investment in the partnership interest.
The election allowed the Company to treat the partnership as a corporation and
look to the "inside tax basis," which represents the tax effected difference
between the book value of the assets and liabilities recorded on the balance
sheet of the partnership and the tax basis of the individual assets and
liabilities. The Company recognized a deferred tax benefit of $144.0 million in
the year ended March 31, 2000 related to this election.
The non U.S. deferred tax provision for the year ended March 31, 2000
included a benefit of $3.2 million due to changes in the Australian tax rate
from 36% to 34% effective April 1, 2000.
59
60
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The income tax rate on income (loss) from continuing operations differed
from the U.S. federal statutory rate as follows (dollars in thousands):
PREDECESSOR
COMPANY
-------------
MAY 20, 1998 APRIL 1, 1998
YEAR ENDED YEAR ENDED TO TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- -------------- -------------
Federal statutory rate.................................... $ 53,513 $ (2,590) $ (187) $ 2,369
Changes in valuation allowance............................ 35,775 31,907 16,386 6,012
Partnership tax basis election............................ -- (144,028) -- --
Foreign earnings and disposition gains.................... (7,079) (2,566) 676 506
State income taxes, net of U.S. federal tax benefit....... (4,912) (6,458) (3,391) 2,881
Depletion................................................. (37,369) (26,151) (13,320) (2,182)
Other, net................................................ 2,762 8,364 2,848 (5,056)
--------- ---------- --------- --------
$ 42,690 $(141,522) $ 3,012 $ 4,530
========= =========== ========= ========
The tax effects of temporary differences that give rise to significant
portions of the deferred tax assets and liabilities consisted of the following
as of March 31:
2001 2000
---------- ----------
(Dollars in thousands)
Deferred tax assets:
Accrued long-term reclamation and mine closing liabilities.................... $ 82,678 $ 71,661
Accrued long-term workers' compensation liabilities........................... 101,700 101,756
Postretirement benefit obligations............................................ 429,035 425,155
Intangible tax asset and purchased contract rights............................ 174,326 211,283
Tax credits and loss carryforwards............................................ 257,796 201,513
Obligation to industry fund................................................... 23,106 26,875
Others........................................................................ 108,097 106,972
---------- ----------
Total gross deferred tax assets.......................................... 1,176,738 1,145,215
---------- ----------
Deferred tax liabilities:
Property, plant, equipment and mine development principally due to
differences in depreciation, depletion and asset writedowns................ 1,339,033 1,373,982
Long-term debt................................................................ 45,579 49,539
Others........................................................................ 173,110 156,883
---------- ----------
Total gross deferred tax liabilities..................................... 1,557,722 1,580,404
---------- ----------
Valuation allowance................................................................ (177,495) (140,066)
---------- ----------
Net deferred tax liability......................................................... $ (558,479) $ (575,255)
========== ==========
Deferred taxes consisted of the following as of March 31:
Current deferred income taxes...................................................... $ 12,226 $ 49,869
Noncurrent deferred income taxes................................................... (570,705) (625,124)
---------- ----------
Net deferred tax liability.................................................... $ (558,479) $ (575,255)
========== ==========
The Company's deferred tax assets include alternative minimum tax ("AMT")
credits of $50.6 million and net operating loss ("NOL") carryforwards of $207.2
million at March 31, 2001. The AMT credits have no expiration date and the NOL
carryforwards expire beginning in the year 2019. The AMT credits and NOL
carryforwards are offset by a valuation allowance of $177.5 million.
The Company made U.S. federal tax payments totaling $0.2 million and $0.3
million for the years ended March 31, 2001 and 2000, respectively. No payments
for U.S. federal taxes were made for the periods ended March 31, 1999 or May 19,
1998. The Company paid state and local income taxes totaling $0.1 million and
$0.6 million for the years ended March 31, 2001 and 2000, respectively, and $0.7
million for the period ended March 31, 1999. The Company made no state or local
income tax payments were made for the period ended May 19, 1998.
60
61
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Non U.S. tax payments were $19.1 million and $8.8 million for the years
ended March 31, 2001 and 2000, respectively and $11.9 million and $0.3 million
for the periods ended March 31, 1999 and May 19, 1998, respectively.
(10) SHORT-TERM BORROWINGS
The Company was not obligated for any short-term borrowings at March 31,
2001. Short-term borrowings were $9.9 million at March 31, 2000.
The Company maintains a Revolving Credit Facility that provides for
aggregate borrowings of up to $200.0 million and letters of credit of up to
$280.0 million. Interest rates on the revolving loans under the Revolving Credit
Facility are based on the Base Rate (as defined in the Senior Credit Facilities)
or LIBOR (as defined in the Senior Credit Facilities) at the Company's option.
The applicable rate was 6.3% at March 31, 2001. The Revolving Credit Facility
commitment matures in fiscal year 2005. As of March 31, 2001, the Company had
$73.4 million of letters of credit outstanding under the Revolving Credit
Facility.
Interest paid was $1.4 million and $2.1 million for the years ended March
31, 2001 and 2000, respectively and $1.4 million and $0.2 million for the
periods ended March 31, 1999 and May 19, 1998, respectively. As of March 31,
2001 and 2000, Lehman Commercial Paper Inc. had committed to provide $18.9
million and $23.3 million of the Company's total available borrowing capacity
under the Revolving Credit Facility.
(11) LONG-TERM DEBT
Long-term debt consisted of the following as of March 31:
2001 2000
----------- -----------
(Dollars in thousands)
Term loans under Senior Credit Facilities due 2006............................. $ 125,000 $ 690,000
9.625% Senior Subordinated Notes ("Senior Subordinated Notes") due
2008........................................................................ 498,854 498,747
8.875% Senior Notes ("Senior Notes") due 2008.................................. 399,062 398,971
5.0% Subordinated Note......................................................... 169,875 180,335
Senior unsecured notes under various agreements................................ 91,429 99,286
Unsecured revolving credit agreement........................................... 69,975 44,721
Other long-term debt........................................................... 51,426 154,171
----------- -----------
Total long-term debt...................................................... 1,405,621 2,066,231
Less current maturities........................................................ (36,305) (48,042)
----------- -----------
Long-term debt, less current maturities................................... $ 1,369,316 $ 2,018,189
=========== ===========
The Senior Credit Facilities are secured by a first priority lien on
certain assets of the Company and its domestic subsidiaries. During fiscal year
2001, the Company made optional prepayments of $565.0 million on the Senior
Credit Facilities, which it applied against mandatory Term Loan A and B payments
in order of maturity. As a result of the prepayments, the Company recorded an
extraordinary loss on debt extinguishment of $8.5 million, net of income taxes.
As of March 31, 2001 and 2000, Lehman Brothers Inc.'s and its affiliates' share
of the Company's term loans outstanding under the Senior Credit Facilities was
$1.8 million and $1.9 million, respectively.
During fiscal year 2001, the Company terminated its interest rate swap
agreements and realized a net gain of approximately $5.1 million which has been
included as a component of interest expense for the year ended March 31, 2001.
In fiscal years 2000 and 1999, the Company maintained interest rate swap
agreements to fix the interest cost on $500 million of long-term debt
outstanding under the Term Loan Facility.
The Senior Subordinated Notes are general unsecured obligations of the
Company and are subordinate in right of payment to all existing and future
senior debt (as defined), including borrowings under the Senior Credit
Facilities and the Senior Notes. The
61
62
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Senior Notes are general unsecured obligations of the Company, rank senior in
right of payment to all subordinated indebtedness (as defined) and rank equally
in right of payment with all current and future unsecured indebtedness of the
Company. As of March 31, 2001 and 2000, Lehman Brothers Inc.'s and its
affiliates' share of the Company's Senior Notes outstanding was $1.1 million and
$3.9 million, respectively. As of March 31, 2001 and 2000, Lehman Brothers
Inc.'s and its affiliates' share of the Company's Senior Subordinated Notes
outstanding was $8.9 million and $12.4 million, respectively.
The indentures governing the Senior Notes and Senior Subordinated Notes
permit the Company and its Restricted Subsidiaries to incur additional
indebtedness, including secured indebtedness, subject to certain limitations. In
addition, among other customary restrictive covenants, the indentures prohibit
the Company and its Restricted Subsidiaries from creating or otherwise causing
any encumbrance or restriction on the ability of any Restricted Subsidiary that
is not a Guarantor to pay dividends or to make certain other upstream payments
to the Company or any of its Restricted Subsidiaries (subject to certain
exceptions). The Revolving Credit Facility and related term loans also contain
certain restrictions and limitations including, but not limited to, financial
covenants that will require the Company to maintain and achieve certain levels
of financial performance and limit the payment of cash dividends and similar
restricted payments. In addition, the Senior Credit Facilities prohibit the
Company from allowing its Restricted Subsidiaries (which include all Guarantors)
to create or otherwise cause any encumbrance or restriction on the ability of
any such Restricted Subsidiary to pay any dividends or make certain other
upstream payments subject to certain exceptions. At March 31, 2001, restricted
net assets of the Company's consolidated subsidiaries was $500.0 million.
The 5.0% Subordinated Note, which had an original face value of $400.0
million, is recorded net of discount at an effective annual interest rate of
approximately 12.0%. Interest and principal are payable each March 1 and
scheduled principal payments of $20.0 million per year are due from 2002 through
2006 with any unpaid amounts due March 1, 2007. The 5.0% Subordinated Note is
expressly subordinated in right of payment to all prior indebtedness (as
defined), including borrowings under the Senior Credit Facilities and the Senior
Notes.
The senior unsecured notes represent obligations of Black Beauty and
include $31.4 million of Senior Notes and three series of notes with an
aggregate principal amount of $60.0 million. The Senior Notes bear interest at
9.2%, payable quarterly, and are prepayable in whole or in part at any time,
subject to certain make-whole provisions. The three series of notes include
Series A, B and C Notes, totaling $45.0 million, $5.0 million, and $10.0
million, respectively. The Series A Notes bear interest at an annual rate of
7.5% and are due in fiscal year 2008. The Series B Notes bear interest at an
annual rate of 7.4% and are due in fiscal year 2004. The Series C Notes bear
interest at an annual rate of 7.4% and are due in fiscal year 2003.
At March 31, 2001, Black Beauty maintained a $100.0 million revolving
credit facility with several banks that matures on February 28, 2002. Black
Beauty may elect one or a combination of interest rates on its borrowings; the
effective annual interest rate was 8.0% at March 31, 2001. Borrowings
outstanding at March 31, 2001 were $70.0 million. Quarterly commitment fees are
paid on the unused portion of the facility at a 0.16% rate.
Other long-term debt at March 31, 2000 included a project finance facility
and capital lease obligations totaling $98.9 million related to the Company's
Australian operations. Other, principally notes payable at March 31, 2001, is
due in installments through 2006 with a weighted average effective interest rate
of 7.6%.
The aggregate amounts of long-term debt maturities subsequent to March 31,
2001 are as follows (dollars in thousands):
2002................................................................... $ 36,305
2003................................................................... 57,742
2004................................................................... 70,225
2005................................................................... 105,645
2006................................................................... 27,913
2007 and thereafter.................................................... 1,107,791
-----------
$ 1,405,621
===========
The amount of interest paid was $184.6 million and $196.9 million for the
years ended March 31, 2001 and 2000, respectively and $138.8 million and $0.5
million for the periods ended March 31, 1999 and May 19, 1998, respectively.
62
63
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(12) WORKERS' COMPENSATION OBLIGATIONS
The workers' compensation obligations consisted of the following as of
March 31:
2001 2000
--------- ---------
(Dollars in thousands)
Occupational disease costs.......................................... $ 159,229 $ 156,729
Traumatic injury claims............................................. 84,704 89,355
State assessment taxes.............................................. 415 1,422
--------- ---------
Total obligations.............................................. 244,348 247,506
Less current portion................................................ (33,568) (35,246)
--------- ---------
Noncurrent obligations......................................... $ 210,780 $ 212,260
========= =========
Workers' compensation obligations consist of amounts accrued for loss
sensitive insurance premiums, uninsured claims, and related taxes and
assessments under traumatic injury and occupational disease workers'
compensation programs. As of March 31, 2001, the Company had $77.4 million in
surety bonds outstanding to secure workers' compensation obligations.
Certain subsidiaries of the Company are subject to the Federal Coal Mine
Health & Safety Act of 1969, and the related workers' compensation laws in the
states in which they operate. These laws require the subsidiaries to pay
benefits for occupational disease resulting from coal workers' pneumoconiosis
("CWP"). The provision for CWP claims (including projected claims costs and
interest discount accruals) was a charge of $11.9 million and a charge of $12.0
million for the years ended March 31, 2001 and 2000, respectively, a charge of
$11.1 million for the period ended March 31, 1999 and a benefit of $0.4 million
for the period ended May 19, 1998.
The Company provides income replacement and medical treatment for work
related traumatic injury claims as required by the applicable state law. The
provision for traumatic injury claims (including projected claims costs and
interest discount accruals) was a charge of $15.7 million and a charge of $16.7
million for the years ended March 31, 2001 and 2000, respectively, a charge of
$16.0 million for the period ended March 31, 1999 and a charge of $2.4 million
for the period ended May 19, 1998.
Certain subsidiaries are required to contribute to state workers'
compensation funds for second injury and other costs incurred by the state fund
based on a payroll based assessment by the applicable state. The provision for
state assessments was a charge of $13.7 million and a charge of $14.0 million
for the years ended March 31, 2001 and 2000, respectively, a charge of $8.8
million for the period ended March 31, 1999 and a charge of $1.3 million for the
period ended May 19, 1998.
The liability for occupational disease claims represents the present value
of known claims and an actuarially-determined estimate of future claims that
will be awarded to current and former employees. The projections at March 31,
2001 were based on a 8.1% per annum interest discount rate and a 3.5% estimate
for the annual rate of inflation. The projections at March 31, 2000 were based
on a 7.125% per annum interest discount rate and a 3.5% estimate for the annual
rate of inflation. Traumatic injury workers' compensation obligations are
estimated from both case reserves and actuarial determinations of historical
trends, discounted at 8.1% and 7.125% per annum at March 31, 2001 and 2000,
respectively.
Federal Black Lung Excise Tax Refund Claims
In addition to the obligations discussed above, certain subsidiaries of the
Company are required to pay Black Lung excise taxes to the Federal Black Lung
Trust Fund. The trust fund pays CWP benefits to entitled former miners who
worked prior to July 1, 1973. Excise taxes are based on the selling price of the
coal, up to a maximum per ton amount.
Pursuant to a Federal District Court ruling, which the Internal Revenue
Service did not appeal, the Black Lung excise tax was declared unconstitutional
for export coal sales. As a result, the Company recorded income of $13.7 million
and $5.0 million during fiscal years 2001 and 2000, respectively, related to
refund claims filed with the Internal Revenue Service. In addition, related
interest income of $3.6 million was recorded during fiscal year 2001.
63
64
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(13) PENSION AND SAVINGS PLANS
Peabody Holding Company sponsors a defined benefit pension plan covering
substantially all salaried U.S. employees (the "Peabody Plan"). A Peabody
Holding Company subsidiary also has a defined benefit pension plan covering
eligible employees who are represented by the United Mine Workers of America
under the Western Surface Agreement of 1996 (the "Western Plan"). Peabody
Holding Company and Gold Fields sponsor separate unfunded supplemental
retirement plans to provide senior management with benefits in excess of limits
under the federal tax law and increased benefits to reflect a service adjustment
factor. Powder River Coal Company, a wholly-owned subsidiary, sponsored a
defined benefit pension plan for its salaried employees that was merged into the
Peabody Plan effective January 1, 1999. Pension benefits were not affected by
the merger. Lee Ranch sponsors two defined benefit pension plans, one which
covers substantially all Lee Ranch hourly employees (the "Lee Ranch Hourly
Plan") and one which covers substantially all Lee Ranch salaried employees (the
"Lee Ranch Salaried Plan").
Benefits under the Peabody Plan and the Lee Ranch Salaried Plan are
computed based on the number of years of service and compensation during certain
years. Benefits under the Western Plan are computed based on the number of years
of service with the subsidiary or other specified employers. Benefits under the
Lee Ranch Hourly Plan are computed based on job classification and years of
service.
Annual contributions to the plans are made as determined by consulting
actuaries based upon the Employee Retirement Income Security Act of 1974 minimum
funding standard. As a result of the acquisition of the Predecessor Company, the
Company entered into an agreement with the Pension Benefit Guaranty Corporation
which requires the Company to maintain minimum funding requirements. Assets of
the plans are primarily invested in various marketable securities, including
U.S. government bonds, corporate obligations and listed stocks. The funds are
part of a master trust arrangement managed by the Company.
Net periodic pension costs included the following components (dollars in
thousands):
PREDECESSOR
COMPANY
--------------
MAY 20, 1998 APRIL 1, 1998
YEAR ENDED YEAR ENDED TO TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- -------------- --------------
Service cost for benefits earned............... $ 8,916 $ 9,773 $ 9,098 $ 2,323
Interest cost on projected benefit obligation.. 37,484 34,389 29,640 7,543
Expected return on plan assets................. (43,932) (42,691) (48,546) (9,125)
Other amortizations and deferrals.............. (2,174) (455) 12,083 --
--------- --------- --------- --------
Net periodic pension costs.................. $ 294 $ 1,016 $ 2,275 $ 741
========= ========= ========= ========
During the period ended March 31, 1999, the Company made an amendment to
phase out the Peabody Plan beginning January 1, 2000 that resulted in a
curtailment gain of $7.1 million. Effective January 1, 2001, certain employees
no longer accrue future service under the plan and certain employees accrue
reduced service under the plan based on their age and years of service at
December 31, 2000. For plan benefit calculation purposes, employee earnings are
also frozen at December 31, 2000. The Company has adopted an enhanced savings
plan contribution structure in lieu of benefits formerly accrued under the
defined benefit pension plan.
64
65
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The following summarizes the change in benefit obligation, change in plan
assets and funded status of the Company's plans:
2001 2000
---------- ----------
(Dollars in thousands)
Change in benefit obligation:
Benefit obligation at beginning of year............................. $ 459,195 $ 492,867
Service cost........................................................ 8,916 9,773
Interest cost....................................................... 37,484 34,389
Plan amendments..................................................... 6,995 --
Benefits paid....................................................... (29,340) (28,506)
Actuarial (gain) loss............................................... 29,654 (49,328)
---------- ----------
Benefit obligation at end of year........................................ 512,904 459,195
---------- ----------
Change in plan assets:
Fair value of plan assets at beginning of year...................... 507,776 474,385
Actual return on plan assets........................................ (611) 60,375
Employer contributions.............................................. 1,029 1,522
Benefits paid....................................................... (29,340) (28,506)
---------- ----------
Fair value of plan assets at end of year................................. 478,854 507,776
---------- ----------
Funded status....................................................... (34,050) 48,581
Unrecognized actuarial (gain) loss.................................. 21,515 (54,773)
Unrecognized prior service cost (benefit)........................... 1,873 (5,205)
---------- ----------
Accrued pension expense.................................................. $ (10,662) $ (11,397)
========== ==========
Amounts recognized in the balance sheets:
Prepaid benefit cost................................................ $ 4,594 $ 2,832
Accrued benefit liability........................................... (23,333) (14,229)
Intangible asset.................................................... 6,600 --
Additional minimum pension liability................................ 1,477 --
---------- ----------
Net amount recognized.................................................... $ (10,662) $ (11,397)
========== ==========
The projected benefit obligation applicable to pension plans with
accumulated benefit obligations in excess of plan assets was $72.9 million and
$13.2 million at March 31, 2001 and 2000, respectively. The accumulated benefit
obligation related to these plans was $71.3 million and $13.0 million at March
31, 2001 and 2000, respectively. The fair value of plan assets related to these
plans was $48.6 million at March 31, 2001 and zero at March 31, 2000.
At March 31, 2001, the projected benefit obligation exceeded plan assets
for all plans. The projected benefit obligation applicable to pension plans with
projected benefit obligations in excess of plan assets was $15.0 million at
March 31, 2000. The plan assets related to these plans was $1.5 million at March
31, 2000.
The provisions of SFAS No. 87, "Employers' Accounting for Pensions,"
require the recognition of an additional minimum liability and related
intangible asset to the extent that accumulated benefits exceed plan assets. As
of March 31, 2001, the Company recorded an adjustment of $1.5 million which was
required to reflect the Company's minimum liability.
The assumptions used to determine the above projected benefit obligation at
the end of each fiscal period were as follows:
MARCH 31, 2001 MARCH 31, 2000
-------------- --------------
Discount rate.................................................... 7.85% 8.1%
Rate of compensation increase.................................... 4.25% 4.25%
Expected rate of return on plan assets........................... 9.0% 9.0%
65
66
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Certain subsidiaries make contributions to multiemployer pension plans,
which provide defined benefits to substantially all hourly coal production
workers represented by the United Mine Workers of America other than those
covered by the Western Plan. Benefits under the United Mine Workers of America
plans are computed based on service with the subsidiaries or other signatory
employers. The amounts contributed to the plans and included in operating costs
were $0.1 million and $0.3 million for the years ended March 31, 2001 and 2000,
respectively, and $1.1 million and $0.6 million for the periods ended March 31,
1999 and May 19, 1998, respectively.
The Company sponsors an employee retirement account for eligible salaried
U.S. employees. The Company matches between 50.0% and 75.0% of voluntary
contributions up to a maximum matching contribution between 3.0% and 6.0% of a
participant's salary. Beginning with fiscal year 2000, a performance
contribution feature was added to the Employee Retirement Account to allow for
contributions up to a maximum of 4% of a participants salary based upon meeting
specified company performance targets. Effective January 1, 2001, the Company
increased the matching contribution to a maximum of 6.0% of a participant's
salary. The expense for these plans was $6.4 million and $6.1 million for the
years ended March 31, 2001 and 2000, respectively, and $4.1 million and $0.6
million for the periods ended March 31, 1999 and May 19, 1998, respectively.
The Company utilizes an alternative method for amortization of actuarial
gains and losses. The method is a 5% corridor and an amortization period of five
years.
(14) POSTRETIREMENT HEALTH CARE AND LIFE INSURANCE BENEFITS
The Company currently provides health care and life insurance benefits to
qualifying salaried and hourly retirees and their dependents from defined
benefit plans established by the Company. Employees of Gold Fields are only
eligible for life insurance benefits as provided by the Company. Plan coverage
for the health and life insurance benefits is provided to future hourly retirees
in accordance with the applicable labor agreement. The Company accounts for
postretirement benefits using the accrual method.
Net periodic postretirement benefits costs included the following
components (dollars in thousands):
PREDECESSOR
COMPANY
---------------
MAY 20, 1998 APRIL 1, 1998
YEAR ENDED YEAR ENDED TO TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999 MAY 19, 1998
-------------- -------------- -------------- --------------
Service cost for benefits earned...................... $ 3,379 $ 4,835 $ 4,750 $ 897
Interest cost on accumulated postretirement benefit
obligations........................................ 74,227 70,029 60,519 10,075
Amortization of prior service cost.................... (2,610) (2,488) (625) (242)
Amortization of actuarial gains....................... (4,339) -- -- --
-------- -------- -------- --------
Net periodic postretirement benefit costs............. $ 70,657 $ 72,376 $ 64,644 $ 10,730
======== ======== ======== ========
66
67
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The following table sets forth the plans' combined funded status reconciled
with the amounts shown in the balance sheets:
2001 2000
------------ ------------
(Dollars in thousands)
Change in benefit obligation:
Benefit obligation at beginning of year............................... $ 964,380 $ 1,008,702
Service cost.......................................................... 3,379 4,835
Interest cost......................................................... 74,227 70,029
Plan amendments....................................................... -- (1,097)
Benefits paid......................................................... (60,589) (57,586)
Actuarial (gain) loss................................................. 9,837 (60,503)
------------ ------------
Benefit obligation at end of year.......................................... 991,234 964,380
------------ ------------
Change in plan assets:
Fair value of plan assets at beginning of year........................ -- --
Employer contributions................................................ 60,589 57,586
Benefits paid......................................................... (60,589) (57,586)
------------ ------------
Fair value of plan assets at end of year................................... -- --
------------ ------------
Funded status......................................................... (991,234) (964,380)
Unrecognized actuarial gain........................................... (27,080) (41,420)
Unrecognized prior service cost....................................... (17,776) (20,386)
------------ ------------
Total accrued postretirement benefit obligation.................. (1,036,090) (1,026,186)
Less current portion....................................................... 62,011 55,000
------------ ------------
Noncurrent obligation............................................ $ (974,079) $ (971,186)
============ ============
The assumptions used to determine the accumulated postretirement benefit
obligation at the end of each fiscal years were as follows:
MARCH 31, 2001 MARCH 31, 2000
------------------ ------------------
Discount rate............................................................... 7.85% 8.1%
Salary increase rate for life insurance benefit............................. 4.25% 4.25%
Health care trend rate:
Pre-65................................................................. 6.95% down to 6.95% down to
4.75% over 4 years 4.75% over 4 years
Post-65................................................................ 6.13% down to 6.13% down to
4.75% over 4 years 4.75% over 4 years
Medicare............................................................... 5.68% down to 5.68% down to
4.75% over 4 years 4.75% over 4 years
Assumed health care cost trend rates have a significant effect on the
amounts reported for health care plans. A one-percentage-point change in the
assumed health care cost trend would have the following effects:
ONE-PERCENTAGE- ONE-PERCENTAGE-
POINT INCREASE POINT DECREASE
-------------- --------------
(Dollars in thousands)
Effect on total service and interest cost components................... $ 9,827 $ (8,169)
Effect on postretirement benefit obligation............................ $ 126,255 $ (105,321)
In October 1999, Powder River announced changes in its medical plan for
active employees and retirees. Employees who retired prior to December 31, 1999
were not affected by these changes. The changes included: 90/10 coinsurance,
maximum out-of-pocket limits, copay for prescription drugs and mandatory generic
drug usage. The effect of the change on the salaried retiree health care
liability is $1.1 million. Powder River is recognizing the effect of the plan
amendment over nine years. The effect for the years ended March 31, 2001 and
2000 was $0.1 million.
67
68
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
In January 1999, the Company adopted reductions to the salaried employee
medical coverage levels for employees retiring before January 1, 2003. For
employees retiring on or after January 1, 2003, the current medical plan is
replaced with a medical premium reimbursement plan. This plan change does not
apply to Powder River or Lee Ranch salaried employees. The change in the retiree
health care plan resulted in a $22.4 million reduction to the salaried retiree
health care liability. The Company is recognizing the effect of the plan
amendment over nine years beginning January 1, 1999. Therefore, the effect was
$2.5 million for each of the years ended March 31, 2001 and 2000, and for the
three months ended March 31, 1999 was $0.6 million.
The Company utilizes an alternative method for amortization of actuarial
gains and losses. The method is a 5% corridor and an amortization period of
three years.
Multi-Employer Pension and Benefit Plans
Retirees formerly employed by certain subsidiaries and their predecessors,
who were members of the United Mine Workers of America, last worked before
January 1, 1976 and were receiving health benefits on July 20, 1992, receive
health benefits provided by the Combined Fund, a fund created by the Coal
Industry Retiree Health Benefit Act of 1992 (the "Coal Act"). The Coal Act
requires former employers (including certain subsidiaries of the Company) and
their affiliates to contribute to the Combined Fund according to a formula. In
addition, certain Federal Abandoned Mine Lands funds will be used to pay
benefits to orphaned retirees through 2004.
The Company has recorded an actuarially determined liability representing
the amounts anticipated to be due for the Combined Fund. The "Obligation to
industry fund" reflected in the balance sheets at March 31, 2001 and 2000 was
$52.2 million and $64.7 million, respectively. The current portion related to
this obligation reflected in "Accounts payable and accrued expenses" in the
balance sheets at March 31, 2001 and 2000 was $5.6 million and $5.1 million,
respectively.
A benefit of $8.0 million was recognized for the period ended March 31,
2001, which includes interest discount of $4.6 million, net amortization of an
actuarial gain of $1.1 million and a gain of $11.5 million related to
beneficiaries formerly assigned to the Company by the Social Security
Administration and withdrawn in the current year. Expense of $2.6 million was
recognized for the period ended March 31, 2000 which includes interest discount
of $4.8 million, net of the amortization of an actuarial gain of $2.2 million.
Expense of $4.5 million was recognized for the period ended March 31, 1999 due
to the interest discount accrual. A benefit of $0.9 million was recognized for
the period ended May 19, 1998 which included amortization of an actuarial gain
of $1.7 million, net of the interest discount accrual of $0.8 million.
The Coal Act also established a multiemployer benefit plan ("1992 Plan") which
will provide medical and death benefits to persons who are not eligible for the
Combined Fund, whose employer and any affiliates are no longer in business and
who retired prior to October 1, 1994. A prior labor agreement established the
1993 United Mine Workers of America Benefit Trust ("1993 Plan") to provide
health benefits for retired miners not covered by the Coal Act. The 1992 Plan
and the 1993 Plan qualify under SFAS No. 106 as multiemployer benefit plans,
which allows the Company to recognize expense as contributions are made. The
amounts related to these funds were $1.9 million and $1.7 million for the years
ended March 31, 2001 and 2000, respectively, and $0.7 million and $0.2 million
for the periods ended March 31, 1999 and May 19, 1998, respectively.
Pursuant to the provisions of the Coal Act and the 1992 Plan, the Company
is required to provide security in an amount equal to three times the cost of
providing health care benefits for one year for all individuals receiving
benefits from the 1992 Plan who are attributable to the Company, plus all
individuals receiving benefits from an individual employer plan maintained by
the Company who are entitled to receive such benefits. In accordance with the
Coal Act and the 1992 Plan, the Company has outstanding surety bonds at March
31, 2001 of $109.3 million. The surety bonds represent security for the
postretirement liability included on the balance sheets.
68
69
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(15) RESTRUCTURING LIABILITY
In conjunction with the acquisition of the Predecessor Company, the Company
established a $39.4 million liability for estimated costs associated with a
restructuring plan resulting from the business combination. The estimate was
comprised of costs associated with restructuring certain management and
administrative functions ("restructuring plan") and exiting certain activities
("exit plan"). The primary actions of the restructuring plan were to eliminate
or significantly downsize administrative functions for operating locations, and
consolidate and relocate administrative functions to the corporate headquarters.
The restructuring activities were substantially complete by September 1998,
resulting in the involuntary termination of 118 employees and the relocation of
102 employees. Costs included severance pay, relocation costs, office closure
costs (primarily non-cancelable leases) and payments due to employees resulting
from the change in ownership. The costs associated with the exit plan relate to
the decision at the date of the acquisition to suspend the operations of the
Rawhide Mine in Wyoming. Exit activities included stabilizing the coal face,
covering the coal pit, sloping the highwall and idling equipment and facilities,
which were necessary to obtain the required approval from state and federal
regulatory agencies to suspend operations. Costs associated with the
restructuring and exit plans have been charged against the liability as
incurred. The total costs charged against the liability were $6.4 million and
$28.8 million for the period ended March 31, 2000 and the year ended March 31,
1999, respectively.
The exit plan was completed in the third quarter of fiscal year 2000 and
the liability was reduced by $3.8 million at that time to reflect the most
recent cost estimates. This amount was recorded as an adjustment to the cost of
the acquisition. The majority of the adjustment related to lower exit plan costs
than originally estimated. The $0.3 million remaining liability as of March 31,
2000 was recorded as an adjustment to the cost of the acquisition during the
year ended March 31, 2001.
The following table displays a rollforward of the restructuring liability
from the acquisition date to March 31, 2001:
MAY 19, MARCH 31, ADJUSTMENT MARCH 31, ADJUSTMENT MARCH 31,
1998 1999 TO COST OF 2000 TO COST OF 2001
BALANCE CHARGES BALANCE CHARGES ACQUISITION BALANCE ACQUISITION BALANCE
-------- -------- -------- -------- ----------- ------- ----------- --------
(Dollars in thousands)
Restructuring plan.... $ 26,154 $(20,536) $ 5,618 $ (4,409) $ (880) $ 329 $ (329) $ --
Exit plan............. 13,214 (8,296) 4,918 (1,995) (2,923) -- -- --
-------- -------- -------- -------- ------- ----- ------ -----
Total............ $ 39,368 $(28,832) $ 10,536 $ (6,404) $(3,803) $ 329 $ (329) $ --
======== ======== ======== ======== ======= ===== ====== =====
(16) STOCKHOLDERS' EQUITY
Preferred Stock
The Company has 14,000,000 authorized shares of $0.01 par value preferred
stock. The Board of Directors is authorized to issue any or all of the preferred
stock. Shares of preferred stock are exchangeable on a one-for-one basis into
shares of Class A common stock upon resolution by the Board of Directors.
Common Stock
The Company has 42,000,000 authorized shares of $0.01 par value Class A
common stock, and 4,200,000 authorized shares of $0.01 par value Class B common
stock. Holders of the Class A and Class B common stock are entitled to one vote
for each share held on all matters submitted to a vote of the stockholders.
Shares of Class B common stock are convertible into shares of Class A common
stock on a one-for-one basis upon a resolution by the Board of Directors, a
change of control, an initial public offering, a recapitalization that does not
result in a change of control or the passing of nine years after the issuance.
Subject to the rights of the holders of the preferred stock, holders of
Class A and Class B common stock are entitled to ratably receive such dividends
as may be declared by the Board of Directors. In the event of liquidation,
dissolution or winding up of the Company, holders of the Class A common stock
are entitled to share ratably in the distribution of all assets remaining after
payment of liabilities, subject to the rights of the preferred stockholders.
Holders of Class B common stock have a junior liquidation right to the holders
of Class A common stock.
69
70
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The Company recognized compensation cost related to grants of Class B
common stock to management of $3.9 million, $0.3 million and $13.1 million
during the years ended March 31, 2001 and 2000 and the period ended March 31,
1999, respectively.
Stock Option Plan
Effective May 19, 1998, the Company adopted the "1998 Stock Purchase and
Option Plan for Key Employees of P&L Coal Holdings Corporation" (the "Plan"),
making 5,638,920 shares of the Company's common stock available for grant. The
Board of Directors may provide such grants in the form of stock, non-qualified
options or incentive stock options.
A portion of the options vest solely on the passage of time ("time
options") to the extent permitted under the Internal Revenue Code. Additionally,
a portion of the options vest at the end of nine and one-half years, whether or
not the applicable performance targets are achieved, but become exercisable
earlier with the achievement of performance goals determined by the Board of
Directors ("performance options"). Time options become fully vested early upon
death, disability, a change in control or a recapitalization event, as defined.
Performance options become fully vested early upon a change on control, a
recapitalization event or an initial public offering, as defined.
During the year ended March 31, 2001, the Company granted 1,456,542 options
to purchase Class A common stock, 371,934 of which are time options and
1,084,608 of which are performance options. During the year ended March 31,
2000, the Company granted 282,275 options to purchase Class A common stock,
81,414 of which are time options and 200,861 of which are performance options.
During the period ended March 31, 1999, the Company granted 5,314,222 options to
purchase Class A common stock, 1,304,639 of which are time options and 4,009,583
of which are performance options. All options have an exercise price of $14.29
per share, and expire 10 years after date of grant.
A summary of outstanding option activity is as follows:
2001 2000 1999
---------- ---------- ----------
Beginning balance........................................................ 5,165,538 5,314,222 --
Granted........................................................ 1,456,542 282,275 5,314,222
Exercised...................................................... -- -- --
Forfeited...................................................... (1,396,570) (430,959) --
---------- ---------- ----------
Outstanding at March 31............................................. 5,225,510 5,165,538 5,314,222
========== ========== ==========
Exercisable at March 31............................................. 779,962 488,025 --
========== ========== ==========
The Company applies APB Opinion No. 25 and related interpretations in
accounting for the Plan. The Company recorded $0.1 million of compensation
expense for stock options granted during the year ended March 31, 2001. The
Company deferred $2.0 million of compensation related to stock option grants as
of that date, $0.8 million of which is expected to be recognized as expense upon
completion of an initial public offering, and $1.2 million of which will be
recognized in subsequent periods as the stock options become exercisable. The
Company recorded no compensation expense for stock options granted during the
period ended March 31, 1999 or the year ended March 31, 2000. The following
table reflects pro forma net income (loss) and earnings (loss) per share had
compensation cost been determined for the Company's non-qualified and incentive
stock options based on the fair value at the grant dates consistent with the
minimum value method set forth under SFAS No. 123, "Accounting for Stock-Based
Compensation:"
YEAR ENDED YEAR ENDED MAY 20, 1998 TO
MARCH 31, 2001 MARCH 31, 2000 MARCH 31, 1999
-------------- -------------- ---------------
Net income (loss):
As reported.................................................... $ 107,060 $ 28,210 $ 1,009
Pro forma...................................................... 105,117 24,842 (2,248)
Earnings (loss) per share:
As reported.................................................... $ 3.10 $ 0.82 $ .03
Pro forma...................................................... 3.04 0.72 (.06)
These pro forma amounts may not be representative of future disclosures
since the estimated fair value of stock options is amortized to expense over the
vesting period, and additional options may be granted in future years.
70
71
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The weighted average fair values of the Company's stock options and the
assumptions used in applying the minimum value method were as follows:
2001 2000 1999
---------- ---------- ----------
Weighted average fair value................................................. $ 5.97 $ 4.71 $ 4.71
Risk-free interest rate..................................................... 5.5% 5.7% 5.7%
Expected option life........................................................ 7 years 7 years 7 years
Dividend yield.............................................................. 0% 0% 0%
The weighted average remaining contractual life of stock options
outstanding as of March 31, 2001 was 7.8 years.
(17) COMPREHENSIVE INCOME
The after-tax components of accumulated other comprehensive income (loss)
are as follows:
TOTAL ACCUMULATED
FOREIGN CURRENCY MINIMUM PENSION OTHER COMPREHENSIVE
TRANSLATION ADJUSTMENT LIABILITY ADJUSTMENT INCOME/(LOSS)
---------------------- -------------------- -------------------
(Dollars in thousands)
PREDECESSOR COMPANY
Beginning balance March 31, 1998................. $ (42,184) $ -- $ (42,184)
Current period change............................ (17,974) -- (17,974)
--------- --------- ---------
Ending balance May 19, 1998...................... $ (60,158) $ -- $ (60,158)
========= ========= =========
------------------------------------------------------------------------------------------------------------------------
Beginning balance May 20, 1998................... $ -- $ -- $ --
Current period change............................ 4,128 (1,795) 2,333
--------- --------- ---------
Ending balance March 31, 1999.................... 4,128 (1,795) 2,333
Current period change............................ (16,795) 1,795 (15,000)
--------- --------- ---------
Ending balance March 31, 2000.................... (12,667) -- (12,667)
Current period change............................ (26,144) (862) (27,006)
Reclassification adjustment resulting from the
sale of Australian operations................. 38,811 -- 38,811
--------- --------- ---------
Ending balance March 31, 2001.................... $ -- $ (862) $ (862)
========= ========= =========
In conjunction with the sale of the Australian operations as discussed in
Note 3, the Company recorded a reduction of the foreign currency translation
adjustment of the Company's Australian operations.
(18) RELATED PARTY TRANSACTIONS
On May 19, 1997, the Predecessor Company, which at the time was owned by
The Energy Group PLC, purchased Citizens Lehman Power, a joint venture formed in
1994 by Lehman Brothers Holdings and a subsidiary of Citizens Energy
Corporation, from Lehman Brothers Holdings, which owned a 50% interest in
Citizens Lehman Power, and from the other owners of Citizens Lehman Power for a
maximum purchase price of $120.0 million, which included (1) an up-front payment
of $20.0 million and (2) up to $100.0 million of future cash payments based on a
formula taking into account the net asset value of Citizens Lehman Power as of
the date of its sale to The Energy Group PLC and any future increase in net
asset value over the period ending on the last day of fiscal year 2002. That
payment obligation was subject to acceleration, under certain circumstances, in
the event of a change of control of The Energy Group PLC. Citizens Lehman Power
was renamed Citizens Power after the 1997 purchase. As a result of the May 19,
1998 acquisition of the Predecessor Company by Lehman Brothers Merchant Banking,
the change of control payment acceleration provisions became effective, and the
Company paid the former owners of Citizens Lehman Power an aggregate of
approximately $93.0 million in full settlement of the deferred purchase price
obligations, with approximately $73.0 million, including $1.0 million of
interest, of that payment made on May 19, 1998 and $21.0 million, including $1.0
71
72
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
million of interest, paid on April 3, 2000. Amounts paid in settlement of the
deferred purchase price obligations, excluding interest, were included in the
cost of the acquisition of Citizens Lehman Power.
Lehman Brothers provided other financial advisory services to the
Predecessor Company in April 1998, for which the Company paid a fee of $0.1
million.
Lehman Brothers Merchant Banking formed the company to acquire the
Predecessor Company and various of its subsidiaries, including Citizens Power,
from The Energy Group PLC on May 19, 1998. In connection with the acquisition,
the Company paid the $73.0 million of obligations of Citizens Power referred to
above. Lehman Brothers advised Lehman Brothers Merchant Banking in connection
with that acquisition. In addition, Lehman Brothers was the initial purchaser in
connection with the sale of the Company's Senior Notes and our Senior
Subordinated Notes. Furthermore, Lehman Commercial Paper Inc. arranged the
Company's Senior Credit Facility and is one of the Company's lenders. Lehman
Brothers and Lehman Commercial Paper Inc. collectively received fees of
approximately $85 million for those services.
As part of the acquisition, Lehman Brothers Holdings Inc. provided a
364-day guarantee facility to trading counterparties of Citizens Power Sales,
the trading subsidiary of Citizens Power, for trades initiated after the
acquisition. Lehman Brothers Holdings received a fee of $0.5 million, plus
reimbursement of expenses, for providing this guarantee facility, which expired
in accordance with its terms in November 1998. There are no further guarantee
obligations outstanding under this facility.
Lehman Brothers served as the placement agent in a financing completed in
January 1999 by a subsidiary of Citizens Power relating to a utility power
contract restructuring, and the Company paid Lehman Brothers a fee of
approximately $0.8 million, plus reimbursement of expenses, for those services.
Lehman Brothers served as the placement agent in a financing completed in
October 1999 by a subsidiary of Citizens Power relating to a utility power
contract restructuring, and the Company paid Lehman Brothers a fee of
approximately $0.8 million, plus reimbursement of expenses, for those services.
Lehman Brothers served as the Company's financial advisor in connection
with the Company's acquisition of an additional 38.3% interest in Black Beauty.
The Company paid Lehman Brothers a fee of approximately $1.3 million, plus
reimbursement of expenses, for those services.
Lehman Brothers served as the Company's financial advisor in connection
with the sale of Citizens Power, which was completed in fiscal year 2001. The
Company paid Lehman Brothers a fee of approximately $1.5 million, plus
reimbursement of expenses, for those services.
Lehman Brothers served as one of the Company's financial advisors in
connection with the sale of the Company's Australian operations, which was
completed on January 29, 2001. The Company paid Lehman Brothers a fee of $2.7
million, plus reimbursement of expenses, for those services.
(19) CONTRACT RESTRUCTURINGS
The Company has periodically agreed to terminate coal supply agreements in
return for payments by the customer. There were no gains related to coal supply
agreement terminations for the year ended March 31, 2001 or the period ended May
19, 1998. The amounts included in "Other revenues" were $13.0 million for the
year ended March 31, 2000 and $5.3 million for the period ended March 31, 1999.
72
73
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(20) FINANCIAL INSTRUMENTS WITH OFF-BALANCE-SHEET RISK
The Company owns a 30.0% interest in a partnership that leases a coal
export terminal from the Peninsula Ports Authority of Virginia under a 30-year
lease that permits the partnership to purchase the terminal at the end of the
lease term for a nominal amount. The partners have severally (but not jointly)
agreed to make payments under various agreements which in the aggregate provide
the partnership with sufficient funds to pay rents and to cover the principal
and interest payments on the floating-rate industrial revenue bonds issued by
the Peninsula Ports Authority, and which are supported by letters of credit from
a commercial bank. The Company's reimbursement obligation to the commercial bank
is in turn supported by a letter of credit totaling $42.8 million.
In December 1999, the Company entered into a 49.0% interest in a joint
venture to develop and rehabilitate an underground mine and prep plant facility.
The partners have severally agreed to guarantee a $32.3 million financing
agreement provided by two commercial banks of which 49.0% ($15.8 million) is
guaranteed by the Company. Principal payments are due beginning April 1, 2001 at
$0.3 million per month for 24 months, then increase to $0.4 million per month
for 20 months beginning April 1, 2003. A final principal payment of $17.1
million is due December 31, 2004. Interest payments are due monthly and accrue
at prime, which was 8.0% at March 31, 2001.
Prior to the sale of the Company's Australian operations, as discussed in
Note 3, Peabody Resources used forward currency contracts to manage its exposure
against foreign currency fluctuations on sales denominated in U.S. dollars.
Realized gains and losses on these contracts were recognized in the same period
as the hedged transactions. The Company had deferred unrealized gains and
(losses) of ($13.9 million) as of March 31, 2000 and $16.2 million as of March
31, 1999.
In the normal course of business, the Company is a party to financial
instruments with off-balance-sheet risk, such as bank letters of credit,
performance bonds and other guarantees, which are not reflected in the
accompanying balance sheets. Such financial instruments are to be valued based
on the amount of exposure under the instrument and the likelihood of performance
being required. In the Company's past experience, virtually no claims have been
made against these financial instruments. Management does not expect any
material losses to result from these off-balance-sheet instruments and,
therefore, is of the opinion that the fair value of these instruments is zero.
(21) FAIR VALUE OF FINANCIAL INSTRUMENTS
SFAS No. 107, "Disclosures About Fair Value of Financial Instruments,"
defines the fair value of a financial instrument as the amount at which the
instrument could be exchanged in a current transaction between willing parties,
other than in a forced or liquidation sale.
The following methods and assumptions were used by the Company in
estimating its fair value disclosures for financial instruments:
Cash and cash equivalents, accounts receivable and accounts payable
and accrued expenses have carrying values which approximate fair value due
to the short maturity or the financial nature of these instruments.
Long-term debt fair value estimates are based on estimated borrowing
rates to discount the cash flows to their present value. The 5.0%
Subordinated Note carrying amount is net of unamortized note discount.
Other noncurrent liabilities include a deferred purchase obligation
related to the prior purchase of a mine facility. The fair value estimate
is based on the same assumption as long-term debt.
Investments and other assets include certain notes receivable with
customers at various interest rates. Notes receivable fair value estimates
are based on estimated borrowing rates to discount the cash flows to their
present values.
73
74
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The carrying amounts and estimated fair values of the Company's financial
instruments are summarized as follows:
2001 2000
--------------------------- ---------------------------
CARRYING ESTIMATED CARRYING ESTIMATED
AMOUNT FAIR VALUE AMOUNT FAIR VALUE
----------- ----------- ----------- -----------
(Dollars in thousands)
Interest rate swaps................................ $ -- $ -- $ -- $ 20,022
Long-term debt..................................... 1,405,621 1,483,996 2,066,231 1,943,440
Deferred purchase obligation....................... 23,301 23,246 28,377 25,033
The fair value of the financial instruments related to coal and emission
allowance trading activities as of March 31, 2001, and the average fair value
during the year ended March 31, 2001, which include energy commodities, are set
forth below:
FAIR VALUE AVERAGE FAIR VALUE
-------------------------- --------------------------
ASSETS LIABILITIES ASSETS LIABILITIES
--------- ----------- -------- -----------
(Dollars in thousands)
Forward contracts.................................. $ 151,212 $ 143,912 $ 78,088 $ 73,560
Option contracts................................... 21,118 19,801 13,471 12,772
--------- --------- -------- --------
Total......................................... $ 172,330 $ 163,713 $ 91,559 $ 86,332
========= ========= ======== ========
The approximate gross contract or notional amounts of financial instruments
are as follows:
FIXED PRICE FIXED PRICE
PAYOR RECEIVER
----------- -----------
(Dollars in thousands)
Forward contracts.................................................... $ 242,812 $ 232,586
Option contracts..................................................... 86,348 108,639
The change in unrealized gain from coal trading activities for the year
ended March 31, 2001 was $4.3 million. The net gain arising from coal and
emission allowance trading activities was $7.8 million and $1.3 million for the
years ended March 31, 2001 and 2000, respectively, and $0.5 million for the
period ended March 31, 1999. There was no net gain or loss from coal and
emission allowance trading activities for the period ended May 19, 1998.
(22) COMMITMENTS AND CONTINGENCIES
Environmental claims have been asserted against a subsidiary of the Company
at 18 sites in the United States. Some of these claims are based on the
Comprehensive Environmental Response Compensation and Liability Act of 1980, as
amended, and on similar state statutes. The majority of these sites are related
to activities of former subsidiaries of the Company.
The Company's policy is to accrue environmental cleanup-related costs of a
noncapital nature when those costs are believed to be probable and can be
reasonably estimated. The quantification of environmental exposures requires an
assessment of many factors, including changing laws and regulations,
advancements in environmental technologies, the quality of information available
related to specific sites, the assessment stage of each site investigation,
preliminary findings and the length of time involved in remediation or
settlement. For certain sites, the Company also assesses the financial
capability of other potentially responsible parties and, where allegations are
based on tentative findings, the reasonableness of the Company's apportionment.
The Company has not anticipated any recoveries from insurance carriers or other
potentially responsible third parties in its balance sheets. The undiscounted
liabilities for environmental cleanup-related costs recorded as part of "Other
noncurrent liabilities" at March 31, 2001 and 2000 were $48.0 million and $57.7
million, respectively. This amount represents those costs that the Company
believes are probable and reasonably estimable.
74
75
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
On June 18, 1999, The Navajo Nation served our subsidiaries, Peabody
Holding Company, Inc., Peabody Coal Company and Peabody Western Coal Company,
with a complaint that had been filed in the U.S. District Court for the District
of Columbia. Other defendants in the litigation are two customers, one current
employee and one former employee. The Navajo Nation has alleged 16 claims,
including Civil Racketeer Influenced and Corrupt Organizations Act, or RICO,
violations and fraud and tortious interference with contractual relationships.
The complaint alleges that the defendants jointly participated in unlawful
activity to obtain favorable coal lease amendments. Plaintiff also alleges that
defendants interfered with the fiduciary relationship between the United States
and the Navajo Nation. The plaintiff is seeking various remedies including
actual damages of at least $600 million, which could be trebled under the RICO
counts, punitive damages of at least $1 billion, a determination that Peabody
Western Coal Company's two coal leases for the Kayenta and Black Mesa mines have
terminated due a breach of these leases and a reformation of the two coal leases
to adjust the royalty rate to 20%. All defendants have filed motions to dismiss
the complaint. On March 15, 2001, the court denied the Peabody defendants'
motions to dismiss.
In March 2000, the Hopi Tribe filed a motion to intervene in this lawsuit.
The Hopi Tribe has alleged seven claims, including fraud. The Hopi Tribe is
seeking various remedies, including unspecified actual and punitive damages,
reformation of its coal lease and a termination of the coal lease. On March 15,
2001, the court granted the Hopi Tribe's motion. On April 17, 2001, the Company
filed a motion to dismiss the Hopi complaint.
The Company believes this matter will be resolved without a material
adverse effect on the financial condition or results of operations.
In addition, the Company at times becomes a party to claims, lawsuits,
arbitration proceedings and administrative procedures in the ordinary course of
business. Management believes that the ultimate resolution of pending or
threatened proceedings will not have a material effect on the financial
position, results of operations or liquidity of the Company.
At March 31, 2001, purchase commitments for capital expenditures were
approximately $94.4 million.
75
76
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(23) SUMMARY QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
The following is a summary of the unaudited quarterly results of operations
for fiscal years 2001 and 2000 (dollars in thousands, except share data):
2001
---------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
----------- ----------- ----------- -----------
Revenues................................................... $ 673,021 $ 677,591 $ 634,081 $ 684,999
Operating profit........................................... 40,957 39,360 52,723 208,799
Income (loss) from continuing operations................... (8,470) (11,233) (2,034) 124,417
Income (loss) before extraordinary item.................... 350 (8,293) (2,034) 125,582
Net income (loss).......................................... 350 (8,293) (2,034) 117,037
Basic and diluted earnings (loss) per share per
share from continuing operations........................ $ (0.25) $ (0.33) $ (0.06) $ 3.60
Weighted average shares used in calculating basic
and diluted earnings (loss) per share................... 27,511,978 27,554,065 27,491,443 27,541,242
2000
----------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
----------- ----------- ----------- ------------
Revenues.................................................... $ 664,400 $ 678,343 $ 709,446 $ 658,311
Operating profit............................................ 41,967 46,703 52,405 52,162
Income (loss) from continuing operations.................... (9,427) (7,057) (6,085) 141,139
Net income (loss)........................................... (12,880) (8,093) (9,705) 58,888
Basic and diluted earnings (loss) per share per
share from continuing operations......................... $ (0.27) $ (0.20) $ (0.18) $ 4.08
Weighted average shares used in calculating basic
and diluted earnings (loss) per share.................... 27,592,277 27,587,335 27,582,549 27,583,350
Results of operations for the first quarter, second quarter and fourth
quarter of fiscal year 2001 included reductions to the after-tax estimated loss
on disposal of Citizens Power of $8.8 million, $3.0 million and $1.1 million,
respectively. Results of operations for the fourth quarter of fiscal year 2001
included an after-tax gain of $124.2 million on the sale of the Company's
Australian operations, and an after-tax extraordinary loss of $8.5 million
related to the early extinguishment of debt. Additionally, results of operations
for the fourth quarter of fiscal year 2000 included a $144.0 million income tax
benefit associated with an increase in the tax basis of a subsidiary's assets
due to a change in federal income tax regulations, and a $78.3 million estimated
loss from the disposal of Citizens Power that was classified as a discontinued
operation in March 2000.
76
77
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(24) SEGMENT INFORMATION
The Company operates primarily in the coal industry. "Other" data
represents an aggregation of the Company's other non-mining entities including
Gold Fields. The Company's material operations outside the U.S. related to its
operations in Australia that were sold in January 2001. The Company's industry
and geographic data for continuing operations were as follows (dollars in
thousands):
PREDECESSOR
MAY 20, COMPANY
YEAR ENDED YEAR ENDED 1998 TO ----------------
MARCH 31, MARCH 31, MARCH 31, APRIL 1, 1998 TO
2001 2000 1999 MAY 19, 1998
----------- ----------- ----------- ----------------
Revenues:
U.S. Mining................................................. $ 2,427,963 $ 2,462,166 $ 1,903,214 $ 269,597
Non U.S. Mining............................................. 238,498 244,347 145,687 20,882
Other....................................................... 3,231 3,987 7,931 179
----------- ----------- ----------- ---------
$ 2,669,692 $ 2,710,500 $ 2,056,832 $ 290,658
=========== =========== =========== =========
Operating profit (loss):
U.S. Mining................................................. $ 277,316 $ 140,699 $ 122,827 $ 6,929
Non U.S. Mining............................................. 53,377 48,355 32,676 2,950
Other....................................................... 11,146 4,183 1,541 (554)
----------- ----------- ----------- ---------
$ 341,839 $ 193,237 $ 157,044 $ 9,325
=========== =========== =========== =========
Depreciation, depletion and amortization:
U.S. Mining................................................. $ 215,450 $ 216,327 $ 155,220 $ 22,475
Non U.S. Mining............................................. 25,518 33,455 23,962 3,041
----------- ----------- ----------- ---------
$ 240,968 $ 249,782 $ 179,182 $ 25,516
=========== =========== =========== =========
Total assets, at March 31:
U.S. Mining................................................. $ 5,035,716 $ 5,038,423 $ 5,141,661
Non U.S. Mining............................................. -- 527,771 494,123
Other....................................................... 173,771 260,655 1,388,147
----------- ------------- -----------
$ 5,209,487 $ 5,826,849 $ 7,023,931
=========== =========== ===========
Capital Expenditures:
U.S. Mining................................................. $ 150,401 $ 150,130 $ 110,622 $ 13,582
Non U.S. Mining............................................. 35,702 28,624 63,898 7,292
Other....................................................... 957 -- -- --
----------- ----------- ----------- ---------
$ 187,060 $ 178,754 $ 174,520 $ 20,874
=========== =========== =========== =========
Revenues:
United States............................................... $ 2,431,194 $ 2,466,153 $ 1,911,145 $ 269,776
Non U.S..................................................... 238,498 244,347 145,687 20,882
----------- ----------- ----------- ---------
$ 2,669,692 $ 2,710,500 $ 2,056,832 $ 290,658
=========== =========== =========== =========
Operating profit:
United States............................................... $ 288,462 $ 144,882 $ 124,368 $ 6,375
Non U.S..................................................... 53,377 48,355 32,676 2,950
----------- ----------- ----------- ---------
$ 341,839 $ 193,237 $ 157,044 $ 9,325
=========== =========== =========== =========
Depreciation, depletion and amortization:
United States............................................... $ 215,450 $ 216,327 $ 155,220 $ 22,475
Non U.S..................................................... 25,518 33,455 23,962 3,041
----------- ----------- ----------- ---------
$ 240,968 $ 249,782 $ 179,182 $ 25,516
=========== =========== =========== =========
Property, plant, equipment and mine development, net, at March 31:
United States............................................... $ 4,322,639 $ 4,388,843 $ 4,386,465
Non U.S..................................................... -- 426,667 411,480
----------- ----------- -----------
$ 4,322,639 $ 4,815,510 $ 4,797,945
=========== =========== ===========
77
78
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
(25) SUPPLEMENTAL GUARANTOR/NON-GUARANTOR FINANCIAL INFORMATION
In accordance with the indentures governing the Senior Notes and Senior
Subordinated Notes, certain wholly-owned U.S. subsidiaries of the Company have
fully and unconditionally guaranteed the Senior Notes and Senior Subordinated
Notes on a joint and several basis. Separate financial statements and other
disclosures concerning the Guarantor Subsidiaries are not presented because
management believes that such information is not material to holders of the
Senior Notes and the Senior Subordinated Notes. The following condensed
historical financial statement information is provided for such
Guarantor/Non-Guarantor Subsidiaries.
SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
YEAR ENDED MARCH 31, 2001
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
--------- ------------ ------------ ------------ ------------
(Dollars in thousands)
Total revenues................................ $ -- $ 1,954,866 $ 772,343 $ (57,517) $ 2,669,692
Costs and expenses:
Operating costs and expenses............. -- 1,633,271 589,336 (57,517) 2,165,090
Depreciation, depletion and
amortization.......................... -- 175,162 65,806 -- 240,968
Selling and administrative expenses...... 4,058 77,190 18,019 -- 99,267
Gain on sale of Australian operations.... -- (171,735) -- -- (171,735)
Net gain on property and equipment
disposals............................. -- (4,667) (1,070) -- (5,737)
Interest expense......................... 158,622 109,420 18,457 (88,813) 197,686
Interest income.......................... (68,655) (27,915) (984) 88,813 (8,741)
--------- ----------- --------- --------- -----------
Income (loss) before income taxes and
minority interests......................... (94,025) 164,140 82,779 -- 152,894
Income tax provision (benefit)........... (33,608) 45,463 30,835 -- 42,690
Minority interests....................... -- -- 7,524 -- 7,524
--------- ----------- --------- --------- -----------
Income (loss) from continuing operations...... (60,417) 118,677 44,420 -- 102,680
Gain from disposal of discontinued
operations, net of income taxes....... (88) (12,837) -- -- (12,925)
--------- ----------- --------- --------- -----------
Income (loss) before extraordinary item....... (60,329) 131,514 44,420 -- 115,605
Extraordinary loss from early
extinguishment of debt, net of income
taxes................................. 8,545 -- -- -- 8,545
--------- ----------- --------- --------- -----------
Net income (loss)............................. $ (68,874) $ 131,514 $ 44,420 $ -- $ 107,060
========= =========== ========= ========= ===========
78
79
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
YEAR ENDED MARCH 31, 2000
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
--------- ------------ ------------ ------------ ------------
(Dollars in thousands)
Total revenues................................. $ -- $ 1,963,823 $ 777,165 $ (30,488) $ 2,710,500
Costs and expenses:
Operating costs and expenses.............. -- 1,651,477 557,675 (30,488) 2,178,664
Depreciation, depletion and
amortization........................... -- 180,287 69,495 -- 249,782
Selling and administrative expenses....... 1,251 72,093 21,912 -- 95,256
Net gain on property and equipment
disposals.............................. -- (6,034) (405) -- (6,439)
Interest expense.......................... 174,949 73,330 21,080 (64,303) 205,056
Interest income........................... (43,896) (23,933) (895) 64,303 (4,421)
--------- ----------- --------- --------- -----------
Income (loss) before income taxes and
minority interests.......................... (132,304) 16,603 108,303 -- (7,398)
Income tax provision (benefit)............ (34,804) (136,307) 29,589 -- (141,522)
Minority interests........................ -- -- 15,554 -- 15,554
--------- ----------- --------- --------- -----------
Income (loss) from continuing operations....... (97,500) 152,910 63,160 -- 118,570
Loss from discontinued operations,
net of income taxes.................... -- -- 12,087 -- 12,087
Loss from disposal of discontinued
operations, net of income taxes........ 783 77,490 -- -- 78,273
--------- ----------- --------- --------- -----------
Net income (loss).............................. $ (98,283) $ 75,420 $ 51,073 $ -- $ 28,210
========= =========== ========= ========= ===========
79
80
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
MAY 20, 1998 TO MARCH 31, 1999
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
--------- ------------ ------------ ------------ ------------
(Dollars in thousands)
Total revenues................................. $ -- $ 1,829,438 $ 229,150 $ (1,756) $ 2,056,832
Costs and expenses:
Operating costs and expenses............. -- 1,494,487 150,987 (1,756) 1,643,718
Depreciation, depletion and
amortization.......................... -- 150,584 28,598 -- 179,182
Selling and administrative expenses...... 13,124 60,142 3,622 -- 76,888
Interest expense......................... 160,068 11,292 4,745 -- 176,105
Interest income.......................... (5,716) (11,897) (914) -- (18,527)
--------- ----------- ---------- -------- -----------
Income (loss) before income taxes and
minority interests......................... (167,476) 124,830 42,112 -- (534)
Income tax provision (benefit)........... (36,873) 31,213 8,672 -- 3,012
Minority interests....................... -- -- 1,887 -- 1,887
--------- ----------- ---------- -------- -----------
Income (loss) from continuing operations...... (130,603) 93,617 31,553 -- (5,433)
Income from discontinued operations,
net of income taxes................... -- -- (6,442) -- (6,442)
--------- ----------- ---------- -------- -----------
Net income (loss)............................. $(130,603) $ 93,617 $ 37,995 $ -- $ 1,009
========= =========== ========== ======== ===========
80
81
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED COMBINED STATEMENTS OF OPERATIONS
APRIL 1, 1998 TO MAY 19, 1998
PREDECESSOR COMPANY
-------------------------------------
NON-
GUARANTOR GUARANTOR
SUBSIDIARIES SUBSIDIARIES COMBINED
------------ ------------ --------
(Dollars in thousands)
Total revenues................................................................... $ 269,776 $ 20,882 $ 290,658
Costs and expenses:
Operating costs and expenses................................................ 229,711 14,417 244,128
Depreciation, depletion and amortization.................................... 22,475 3,041 25,516
Selling and administrative expenses......................................... 11,523 494 12,017
Net gain on property and equipment disposals................................ (308) (20) (328)
Interest expense............................................................ 3,856 366 4,222
Interest income............................................................. (1,615) (52) (1,667)
--------- -------- ---------
Income before income taxes....................................................... 4,134 2,636 6,770
Income tax provision........................................................ 3,185 1,345 4,530
--------- -------- ---------
Income from continuing operations................................................ 949 1,291 2,240
Loss from discontinued operations, net of income taxes...................... -- 1,764 1,764
--------- -------- ---------
Net income (loss)................................................................ $ 949 $ (473) $ 476
========= ======== =========
81
82
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED BALANCE SHEETS
AS OF MARCH 31, 2001
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
----------- ------------ ------------ ------------ ------------
(Dollars in thousands)
ASSETS
Current assets
Cash and cash equivalents............. $ 173 $ 57,194 $ 5,356 $ -- $ 62,723
Accounts receivable................... -- 122,582 105,298 (80,072) 147,808
Inventories........................... -- 195,082 15,130 -- 210,212
Assets from coal and emission
allowance trading activities....... -- 172,330 -- -- 172,330
Deferred income taxes................. -- 12,226 -- -- 12,226
Other current assets.................. 4,250 12,370 8,036 -- 24,656
----------- ----------- --------- ------------ -----------
Total current assets............. 4,423 571,784 133,820 (80,072) 629,955
Property, plant, equipment and mine
development, at cost.................... -- 4,435,413 424,586 -- 4,859,999
Less accumulated depreciation, depletion
and amortization........................ -- (479,655) (57,705) -- (537,360)
----------- ----------- --------- ------------ -----------
Property, plant, equipment and mine
development, net........................ -- 3,955,758 366,881 -- 4,322,639
Investments and other assets............... 1,251,550 1,942,193 486,473 (3,423,323) 256,893
----------- ----------- --------- ------------ -----------
Total assets..................... $ 1,255,973 $ 6,469,735 $ 987,174 $ (3,503,395) $ 5,209,487
=========== =========== ========= ============ ===========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Short-term borrowings and current
maturities of long-term debt....... $ -- $ 20,395 $ 15,910 $ -- $ 36,305
Payable to affiliates, net............ (486,736) 495,111 (8,375) -- --
Income taxes payable.................. -- 491 -- -- 491
Liabilities from coal and emission
allowance trading activities....... -- 163,713 -- -- 163,713
Accounts payable and accrued
expenses........................... 88,555 520,111 47,882 (80,072) 576,476
----------- ----------- --------- ------------ -----------
Total current liabilities........ (398,181) 1,199,821 55,417 (80,072) 776,985
Long-term debt, less current maturities.... 1,022,916 151,319 195,081 -- 1,369,316
Deferred income taxes...................... -- 570,657 48 -- 570,705
Other noncurrent liabilities............... -- 1,811,419 8,366 -- 1,819,785
----------- ----------- --------- ------------ -----------
Total liabilities................ 624,735 3,733,216 258,912 (80,072) 4,536,791
Minority interests......................... -- -- 41,458 -- 41,458
Stockholders' equity....................... 631,238 2,736,519 686,804 (3,423,323) 631,238
----------- ----------- --------- ------------ -----------
Total liabilities and
stockholders' equity.......... $ 1,255,973 $ 6,469,735 $ 987,174 $ (3,503,395) $ 5,209,487
=========== =========== ========= ============ ===========
82
83
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED BALANCE SHEETS
AS OF MARCH 31, 2000
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
----------- ------------ ------------- ------------ ------------
(Dollars in thousands)
ASSETS
Current assets
Cash and cash equivalents......... $ 347 $ 45,931 $ 19,340 $ -- $ 65,618
Accounts receivable............... 1,605 95,055 92,083 (35,722) 153,021
Inventories....................... -- 187,965 54,185 -- 242,150
Assets from coal and emission
allowance trading activities... -- 78,695 -- -- 78,695
Deferred income taxes............. -- 49,869 -- -- 49,869
Other current assets.............. 1,282 14,351 27,559 -- 43,192
----------- ----------- ----------- ------------ -----------
Total current assets......... 3,234 471,866 193,167 (35,722) 632,545
Property, plant, equipment and
mine development, at cost...... -- 4,360,648 866,132 -- 5,226,780
Less accumulated depreciation,
depletion and amortization..... -- (323,870) (87,400) -- (411,270)
----------- ------------ ------------ ------------ ------------
Property, plant, equipment and
mine development, net.......... -- 4,036,778 778,732 -- 4,815,510
Net assets of discontinued
operations..................... 900 89,100 -- -- 90,000
Investments and other assets...... 1,883,781 1,444,307 208,095 (3,247,389) 288,794
----------- ----------- ----------- ------------ -----------
Total assets................. $ 1,887,915 $ 6,042,051 $ 1,179,994 $ (3,283,111) $ 5,826,849
=========== =========== =========== ============ ===========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Short-term borrowings and
current maturities of
long-term debt................. $ -- $ 21,122 $ 36,855 $ -- $ 57,977
Payable to affiliates, net........ (284,294) 319,473 (35,179) -- --
Income taxes payable.............. -- 521 13,073 -- 13,594
Liabilities from coal and
emission allowance trading
activities..................... -- 75,883 -- -- 75,883
Accounts payable and accrued
expenses....................... 76,066 416,505 116,288 (35,722) 573,137
----------- ----------- ----------- ------------- -----------
Total current liabilities.... (208,228) 833,504 131,037 (35,722) 720,591
Long-term debt, less current
maturities..................... 1,587,717 162,116 268,356 -- 2,018,189
Deferred income taxes............. -- 567,918 57,206 -- 625,124
Other noncurrent liabilities...... -- 1,873,508 39,746 -- 1,913,254
----------- ----------- ----------- ------------ -----------
Total liabilities............ 1,379,489 3,437,046 496,345 (35,722) 5,277,158
Minority interests................ -- -- 41,265 -- 41,265
Stockholders' equity.............. 508,426 2,605,005 642,384 (3,247,389) 508,426
----------- ----------- ----------- ------------ -----------
Total liabilities and
stockholders' equity...... $ 1,887,915 $ 6,042,051 $ 1,179,994 $ (3,283,111) $ 5,826,849
=========== =========== =========== ============ ===========
83
84
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
YEAR ENDED MARCH 31, 2001
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES CONSOLIDATED
---------- ------------ ------------ ------------
(Dollars in thousands)
Net cash provided by (used in) operating activities......... $ (20,172) $ 113,212 $ 58,940 $ 151,980
Additions to property, plant, equipment and mine
development......................................... -- (94,577) (56,781) (151,358)
Additions to advance mining royalties.................. -- (8,785) (11,475) (20,260)
Acquisitions, net...................................... -- (10,502) -- (10,502)
Proceeds from sale of Australian operations............ -- 455,000 -- 455,000
Proceeds from property and equipment disposals......... -- 7,711 11,214 18,925
Proceeds from sale-leaseback transactions.............. -- 28,800 -- 28,800
Net cash used in assets sold--Australian
operations.......................................... -- -- (34,684) (34,684)
---------- --------- --------- ----------
Net cash provided by (used in) continuing operations........ -- 377,647 (91,726) 285,921
Net cash provided by discontinued operations................ 604 101,937 --- 102,541
---------- --------- --------- ----------
Net cash provided by (used in) investing activities......... 604 479,584 (91,726) 388,462
---------- --------- --------- ----------
Proceeds from short-term borrowings and long-term
debt................................................ -- -- 65,302 65,302
Payments of short-term borrowings and long-term
debt................................................ (565,000) (21,063) (47,842) (633,905)
Distributions to minority interests.................... -- --- (4,690) (4,690)
Dividend received...................................... -- 19,916 -- 19,916
Proceeds from sale of treasury stock................... -- 562 -- 562
Repurchase of treasury stock........................... -- (1,113) -- (1,113)
Other.................................................. 584,394 (579,835) (4,559) --
Net cash provided by assets sold--Australian
operations.......................................... -- -- 10,591 10,591
---------- --------- --------- ----------
Net cash provided by (used in) financing activities......... 19,394 (581,533) 18,802 (543,337)
---------- --------- --------- ----------
Net increase (decrease) in cash and cash equivalents........ (174) 11,263 (13,984) (2,895)
Cash and cash equivalents at beginning of year.............. 347 45,931 19,340 65,618
---------- --------- --------- ----------
Cash and cash equivalents at end of year.................... $ 173 $ 57,194 $ 5,356 $ 62,723
========== ========= ========= ==========
84
85
PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
YEAR ENDED MARCH 31, 2000
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES CONSOLIDATED
--------- ------------ ------------ ------------
(Dollars in thousands)
Net cash provided by (used in) continuing operations ........ $ (83,810) $ 283,472 $ 103,753 $ 303,415
Net cash used in discontinued operations .................... -- -- (40,504) (40,504)
--------- --------- --------- ---------
Net cash provided by (used in) operating activities ......... (83,810) 283,472 63,249 262,911
--------- --------- --------- ---------
Additions to property, plant, equipment and mine
development ......................................... -- (106,593) (72,161) (178,754)
Additions to advance mining royalties .................. -- (7,475) (17,817) (25,292)
Acquisitions, net ...................................... -- -- (63,265) (63,265)
Investment in joint venture ............................ -- (4,325) -- (4,325)
Proceeds from coal contract restructurings ............. -- 11,904 21,000 32,904
Proceeds from property and equipment disposals ......... -- 9,637 9,647 19,284
Proceeds from sale-leaseback transactions .............. -- 34,234 -- 34,234
--------- --------- --------- ---------
Net cash used in continuing operations ...................... -- (62,618) (122,596) (185,214)
Net cash used in discontinued operations .................... -- -- (170) (170)
--------- --------- --------- ---------
Net cash used in investing activities ....................... -- (62,618) (122,766) (185,384)
--------- --------- --------- ---------
Proceeds from short-term borrowings and long-term
debt ................................................ -- -- 22,026 22,026
Payments of short-term borrowings and long-term
debt ................................................ (171,088) (21,695) (17,202) (209,985)
Capital contribution (distribution) .................... -- (1,073) 1,073 --
Distributions to minority interests .................... -- -- (3,353) (3,353)
Dividends (paid) received .............................. 121,903 15,422 (137,325) --
Other .................................................. 133,342 (298,438) 165,096 --
--------- --------- --------- ---------
Net cash provided by (used in) continuing operations ........ 84,157 (305,784) 30,315 (191,312)
Net cash used in discontinued operations .................... -- -- (13,869) (13,869)
--------- --------- --------- ---------
Net cash provided by (used in) financing activities ......... 84,157 (305,784) 16,446 (205,181)
Effect of exchange rate changes on cash and
equivalents ......................................... -- -- (806) (806)
--------- --------- --------- ---------
Net increase (decrease) in cash and cash equivalents ........ 347 (84,930) (43,877) (128,460)
Cash and cash equivalents at beginning of year .............. -- 130,861 63,217 194,078
--------- --------- --------- ---------
Cash and cash equivalents at end of year .................... $ 347 $ 45,931 $ 19,340 $ 65,618
========= ========= ========= =========
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PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
MAY 20, 1998 TO MARCH 31, 1999
NON-
PARENT GUARANTOR GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES CONSOLIDATED
----------- ------------ ------------ ------------
(Dollars in thousands)
Net cash provided by (used in) continuing
operations ................................................ $ (140,674) $ 407,889 $ 63,708 $ 330,923
Net cash used in discontinued operations ..................... -- -- (48,901) (48,901)
----------- ----------- ----------- -----------
Net cash provided by (used in) operating activities .......... (140,674) 407,889 14,807 282,022
----------- ----------- ----------- -----------
Additions to property, plant, equipment and mine
development .......................................... -- (108,186) (66,334) (174,520)
Additions to advance mining royalties ................... -- (8,836) (2,673) (11,509)
Acquisitions, net ....................................... (1,933,178) (143,742) (33,480) (2,110,400)
Proceeds from coal contract restructurings .............. -- 2,515 2,515
Proceeds from property and equipment
disposals ............................................ -- 10,494 954 11,448
----------- ----------- ----------- -----------
Net cash used in continuing investing activities ............. (1,933,178) (247,755) (101,533) (2,282,466)
Net cash provided by discontinued operations ................. -- -- 33,130 33,130
----------- ----------- ----------- -----------
Net cash used in investing activities ........................ (1,933,178) (247,755) (68,403) (2,249,336)
----------- ----------- ----------- -----------
Proceeds from short-term borrowings and long-
term debt ............................................ 1,817,390 -- 53,388 1,870,778
Payments of short-term borrowings and long-term
debt ................................................. (158,263) (21,470) (42,982) (222,715)
Capital contribution .................................... 480,000 -- -- 480,000
Distributions to minority interests ..................... -- 9,096 (12,176) (3,080)
Other ................................................... (65,275) (16,899) 48,158 (34,016)
----------- ----------- ----------- -----------
Net cash provided by (used in) continuing financing
activities ................................................ 2,073,852 (29,273) 46,388 2,090,967
Net cash provided by discontinued operations ................. -- -- 70,314 70,314
----------- ----------- ----------- -----------
Net cash provided by (used in) financing activities .......... 2,073,852 (29,273) 116,702 2,161,281
Effect of exchange rate changes on cash and
equivalents .......................................... -- -- 111 111
----------- ----------- ----------- -----------
Net increase in cash and cash equivalents .................... -- 130,861 63,217 194,078
Cash and cash equivalents at beginning of period ............. -- -- -- --
----------- ----------- ----------- -----------
Cash and cash equivalents at end of period ................... $ -- $ 130,861 $ 63,217 $ 194,078
=========== =========== =========== ===========
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PEABODY ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
SUPPLEMENTAL CONDENSED COMBINED STATEMENTS OF CASH FLOWS
APRIL 1, 1998 TO MAY 19, 1998
PREDECESSOR COMPANY
------------------------------------------------
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES COMBINED
--------------- ------------- ----------
(Dollars in thousands)
Net cash provided by (used in) continuing operations ................. $ (41,999) $ 12,138 $ (29,861)
Net cash provided by discontinued operations ......................... -- 1,704 1,704
--------- --------- ---------
Net cash provided by (used in) operating activities .................. (41,999) 13,842 (28,157)
--------- --------- ---------
Additions to property, plant, equipment and mine development .... (13,582) (7,292) (20,874)
Additions to advance mining royalties ........................... (1,767) (535) (2,302)
Proceeds from coal contract restructurings ...................... 308 20 328
Proceeds from property and equipment disposals .................. 1,374 -- 1,374
--------- --------- ---------
Net cash used in continuing investing activities ..................... (13,667) (7,807) (21,474)
Net cash used in discontinued operations ............................. -- (76) (76)
--------- --------- ---------
Net cash used in investing activities ................................ (13,667) (7,883) (21,550)
--------- --------- ---------
Proceeds from short-term borrowings and long-term debt .......... -- 53,597 53,597
Payments of short-term borrowings and long-term debt ............ (464) (18,959) (19,423)
Dividends paid .................................................. (141,000) (32,330) (173,330)
Other ........................................................... 141,831 (831) 141,000
--------- --------- ---------
Net cash provided by continuing financing activities ................. 367 1,477 1,844
Net cash provided by discontinued operations ......................... -- 21,693 21,693
--------- --------- ---------
Net cash provided by financing activities ............................ 367 23,170 23,537
Effect of exchange rate changes on cash and equivalents ......... -- (292) (292)
--------- --------- ---------
Net increase (decrease) in cash and cash equivalents ................. (55,299) 28,837 (26,462)
Cash and cash equivalents at beginning of period ..................... 83,812 13,009 96,821
--------- --------- ---------
Cash and cash equivalents at end of period ........................... $ 28,513 $ 41,846 $ 70,359
========= ========= =========
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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT.
Set forth below are the names, ages as of March 31, 2001 and current
positions with us and our subsidiaries of our executive officers and directors.
Directors are elected at the annual meeting of stockholders. Executive officers
are appointed by, and hold office at, the discretion of the directors.
NAME AGE POSITION
---- --- --------
Irl F. Engelhardt........................ 54 Chairman, Chief Executive Officer and Director
Richard M. Whiting....................... 46 President, Chief Operating Officer and Director
Roger B. Walcott, Jr..................... 45 Executive Vice President-Corporate Development
Richard A. Navarre....................... 40 Executive Vice President and Chief Financial Officer
Fredrick D. Palmer....................... 56 Executive Vice President-Legal and External Affairs and Secretary
Paul H. Vining........................... 46 Executive Vice President-Sales and Trading
Jeffery L. Klinger....................... 54 Vice President-Legal Services and Assistant Secretary
Sharon D. Fiehler........................ 44 Vice President-Human Resources
Roger H. Goodspeed....................... 50 Director
Henry E. Lentz........................... 56 Director
Alan H. Washkowitz....................... 60 Director
Irl F. Engelhardt served as our President and Chief Executive Officer from
1990 to 1995 and our Chairman and Chief Executive Officer since 1993, and has
been a director since June 1998. Since joining our company in 1979, he has held
various officer level positions in the executive, sales, business development
and administrative areas, including serving as Chairman of Peabody Resources
Ltd. (Australia) and Chairman of Citizens Power. Mr. Engelhardt also served as
Co-Chief Executive Officer and executive director of The Energy Group from
February 1997 to May 1998, Chairman of Cornerstone Construction & Materials,
Inc. from September 1994 to May 1995 and Chairman of Suburban Propane Company
from May 1995 to February 1996. He also served as a director and Group Vice
President of Hanson Industries from 1995 to 1996. Mr. Engelhardt is Co-Chairman
of the Coal Utilization Research Council, Co-Chairman of the Coal Based
Generators Stakeholders Group and past Chairman of the National Mining
Association and the Coal Industry Advisory Board of the International Energy
Agency. He is also a director of Firstar Bank, N.A. (formerly Mercantile Bank of
St. Louis, N.A.).
Richard M. Whiting has been President and Chief Operating Officer of our
company since January 1998 and has been a director since June 1998. He served as
President of Peabody COALSALES Company from June 1992 to January 1998. Since
joining our company in 1976, Mr. Whiting has held a number of operations, sales
and engineering positions both at the corporate offices and at field locations.
From 1989 to 1990, Mr. Whiting served as Vice President of Engineering and
Operations Support. Mr. Whiting is currently Chairman of the Bituminous Coal
Operators' Association, Chairman of the National Mining Association's Safety and
Health Committee and a member of the National Coal Council.
Roger B. Walcott, Jr. has been Executive Vice President-Corporate
Development of our company since February 2001. Prior to that, he was Executive
Vice President of our company since June 1998. From 1981 to 1998, he was a
Senior Vice President and a director with The Boston Consulting Group where he
served a variety of clients in strategy and operational assignments. He was also
Chairman of The Boston Consulting Group's Human Resource Capabilities Committee.
Mr. Walcott holds an MBA with high distinction from the Harvard Business School.
Richard A. Navarre has been Executive Vice President and Chief Financial
Officer of our company since February 2001. Prior to that, he was Vice
President-Chief Financial Officer of our company since October 1999. Prior to
that, he was President of Peabody COALSALES Company from January 1998 to October
1999 and previously served as President of Peabody Energy Solutions, Inc. Prior
to his roles in sales and marketing, he was Vice President of Finance and served
as our Vice President and
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Controller. He joined our company in 1993 as Director of Financial Planning.
Prior to joining us, Mr. Navarre was a senior manager with KPMG Peat Marwick.
Mr. Navarre is a member of the Trade and International Affairs Committee and the
Transportation Committee of the National Mining Association. He is also a member
of the NYMEX Coal Advisory Council. He also serves on the Board of Advisors to
the College of Business for Southern Illinois University.
Fredrick D. Palmer has been Executive Vice President-Legal and External
Affairs of our company since February 2001. He is responsible for our legal
affairs, state and federal government affairs, public relations and investor
relations. Prior to joining Peabody, he served for 15 years as chief executive
officer of Western Fuels Association, Inc. He most recently was of counsel in
the Washington, D.C. office of Shook Hardy & Bacon, a Kansas City-based law
firm. He received a BA and a JD from the University of Arizona.
Paul H. Vining has been Executive Vice President-Sales and Trading of our
company since February 2001. Prior to that, he was President of Peabody
COALSALES Company from October 1999 to January 2001, and President of Peabody
COALTRADE, Inc. from March 1997 to October 1999, and Senior Vice President of
Peabody COALSALES Company from August 1995 to February 1997. Mr. Vining is a
member of the board of directors of the Coal Exporters Association.
Jeffery L. Klinger has been Vice President-Legal Services of our company
since May 1998. Prior to that, he had been our Vice President, Secretary and
Chief Legal Officer since October 1990. From 1986 to October 1990, he served as
Eastern Regional Counsel for Peabody Holding Company and from 1982 to 1986 as
Director of Legal and Public Affairs, Eastern Division of Peabody Coal Company
and joined Peabody as Director of Legal and Public Affairs, Indiana Division of
Peabody Coal Company from 1978 to 1982. He is a past President of the Indiana
Coal Council and is currently a trustee of the Energy and Mineral Law Foundation
and a past Treasurer and member of their Executive Committee. Mr. Klinger is
also a member of the National Mining Association's Legal Affairs Committee.
Sharon D. Fiehler has been Vice President of Human Resources of our company
since 1991, with executive responsibility for employee development, benefits,
compensation, employee relations and affirmative action programs. She joined
Peabody in 1981 as Manager-Salary Administration and has held a series of
employee relations, compensation and salaried benefits positions. Prior to
joining Peabody, Ms. Fiehler, who earned degrees in social work and psychology
and an MBA, was a personnel representative for Ford Motor Company. Ms. Fiehler
is a member of the National Mining Association's Human Resource Committee.
Roger H. Goodspeed became a director of our company in May 1998. He is also
a Managing Director of Lehman Brothers. He joined Lehman Brothers in 1974 and
became a Managing Director in 1984. During his tenure at Lehman Brothers, he has
served in management positions for several different groups. In 1994, he became
the original Chairman of Citizens Lehman Power, an electric power marketing
joint venture 50%-owned by Lehman Brothers, and continued in that role until the
joint venture was sold to The Energy Group in 1997 and changed its name to
Citizens Power. Mr. Goodspeed received an MBA from the Anderson School at the
University of California, Los Angeles.
Henry E. Lentz became a director of our company in February 1998. He is
also a Managing Director of Lehman Brothers and a principal of the firm's
Merchant Banking Group. Mr. Lentz joined Lehman Brothers in 1971 and became a
Managing Director in 1976. In 1988, Mr. Lentz left Lehman Brothers to serve as
Vice Chairman of Wasserstein Perella Group, Inc. In 1993, he returned to Lehman
Brothers as a Managing Director and, prior to joining the Merchant Banking
Group, served as head of the firm's worldwide energy practice. Mr. Lentz is
currently a director of Rowan Companies, Inc. and Consort Holdings plc. Mr.
Lentz holds an MBA, with honors, from the Wharton School of the University of
Pennsylvania.
Alan H. Washkowitz became a director of our company in May 1998. He is also
a Managing Director of Lehman Brothers and the head of the firm's Merchant
Banking Group, responsible for the oversight of Lehman Brothers Merchant Banking
Partners II L.P. Mr. Washkowitz joined Kuhn Loeb & Co. in 1968 and became a
general partner of Lehman Brothers in 1978 when it acquired Kuhn Loeb & Co.
Prior to joining the Merchant Banking Group, Mr. Washkowitz headed Lehman
Brothers' Financial Restructuring Group. He is currently a director of CP Kelco
ApS, L-3 Communications Corporation, K&F Industries, Inc. and McBride plc. Mr.
Washkowitz holds an MBA from Harvard University and a JD from Columbia
University.
Our board of directors is currently comprised of five directors, and we
expect to add two independent members to our board of directors within three
months and a third independent member to our board of directors within 12 months
after May 2001, when our initial public offering was completed. In addition, we
expect that as long as Lehman Brothers Merchant Banking controls us, they will
add additional members to our board of directors so that Lehman Brothers
Merchant Banking will continue to control a majority of our board of directors.
In accordance with the terms of our certificate of incorporation, the board of
directors will be divided into three classes, each serving staggered three-year
terms: Class I, whose initial term will expire at the annual meeting of
stockholders held in 2002; Class II, whose initial term will expire at the
annual meeting of stockholders in 2003; and Class III,
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whose initial term will expire at the annual meeting of stockholders in 2004. As
a result, only one class of directors will be elected at each annual meeting of
our stockholders, with the other classes continuing for the remainder of their
respective terms. Roger Goodspeed has been designated as a Class I director;
Messrs. Whiting and Lentz have been designated as Class II directors; and
Messrs. Engelhardt and Washkowitz have been designated as Class III directors.
In addition, our certificate of incorporation and by-laws provide that directors
may be removed only for cause and only upon the affirmative vote of holders of
at least 75% of the voting power of all the outstanding shares of stock entitled
to vote generally in the election of directors, voting together as a single
class. There are no family relationships among any of our directors and
executive officers.
SECTION 16(A) BENEFICIAL OWNERSHIP REPORTING COMPLIANCE
Section 16(a) of the Securities Exchange Act of 1934 requires our executive
officers, directors and persons who own beneficially more than 10% of our common
stock to file with the SEC initial reports of ownership and reports of changes
in ownership of our common stock and other equity securities. These persons are
required by SEC regulation to furnish us with copies of all Section 16(a)
reports they file with the SEC.
Based solely on our review of copies of such reports furnished to us, we
believe our executive officers, directors, and greater than 10% beneficial
owners complied with all Section 16(a) filing requirements since our initial
public offering on May 22, 2001. Prior to our initial public offering, these
persons were not subject to the Section 16(a) filing requirements.
ITEM 11. EXECUTIVE COMPENSATION.
The following table sets forth the annual compensation for our chief
executive officer and the four most highly compensated executive officers (the
named executive officers, other than the chief executive officer) for their
services to our company during fiscal years 2001, 2000 and 1999.
SUMMARY COMPENSATION TABLE
ANNUAL
COMPENSATION LONG-TERM COMPENSATION
------------------- ------------------------------------------------------
RESTRICTED SECURITIES
STOCK UNDERLYING LTIP ALL OTHER
FISCAL SALARY BONUS AWARD(S) OPTIONS/SARS PAYMENTS COMPENSATION
NAME AND PRINCIPAL POSITION YEAR ($) ($) (#)(1) (#)(2) ($)(3) ($)(4)
-------------------------------------------- ------ -------- --------- ---------- ------------ -------- ------------
Irl F. Engelhardt........................... 2001 700,000 1,050,000 -- 64,019 -- 56,434
Chairman, Chief Executive Officer 2000 700,000 875,000 -- -- -- 51,525
and Director 1999 681,264 700,000 216,495 699,797 441,240 23,998
Richard M. Whiting.......................... 2001 400,000 600,000 -- 22,696 -- 31,630
President, Chief Operating Officer 2000 400,000 500,000 -- -- -- 28,662
and Director 1999 385,834 400,000 72,164 251,759 168,051 12,238
Roger B. Walcott, Jr. ...................... 2001 350,000 525,000 -- 22,696 -- 27,530
Executive Vice President-- 2000 350,000 437,500 72,164 -- -- 24,955
Corporate Development 1999 291,667 350,000 -- 251,759 -- 8,374
Richard A. Navarre.......................... 2001 250,000 406,250 -- 55,084 -- 19,615
Executive Vice President and 2000 233,750 343,750 -- -- -- 17,203
Chief Financial Officer 1999 220,000 220,000 54,124 188,863 45,030 6,824
Paul H. Vining.............................. 2001 262,500 517,624 36,971 148,698 -- 20,820
Executive Vice President-- 2000 208,120 293,540 9,936 76,861 -- 15,536
Sales and Trading 1999 190,000 172,765 7,217 49,000 -- 5,962
--------------
(1) Represents number of shares of common stock granted to executives as of May
19, 1998. In addition, shares purchased by Mr. Walcott on May 19, 1998 were
converted to granted shares during the year ended March 31, 2000.
(2) Represents number of shares of common stock underlying options.
(3) Represents certain long-term incentive payments earned during the fiscal
year that relate to our predecessor company's compensation plans.
(4) Represents annual matching contributions and performance contributions to
qualified and non-qualified savings and investment plans and group term
life insurance.
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OPTION/SAR GRANTS IN FISCAL YEAR 2001
INDIVIDUAL GRANTS
-----------------------------------------
PERCENT OF
TOTAL
NUMBER OF OPTIONS/SARS POTENTIAL REALIZABLE VALUE AT ASSUMED
SECURITIES GRANTED TO ANNUAL RATES OF STOCK PRICE
UNDERLYING EMPLOYEES IN EXERCISE OR APPRECIATION FOR OPTION TERM
OPTIONS/SARS FISCAL BASE PRICE --------------------------------------
NAME GRANTED (#) YEAR 2001 ($/SHARE) EXPIRATION DATE 5% ($) 10% ($)
---------------------------------------------- ------------ ------------ ----------- --------------- ------- --------
Irl F. Engelhardt
Time....................................... 14,214 3.8% 14.29 January 1, 2011 127,743 323,558
Performance................................ 10,811 3.1% 14.29 January 1, 2011 97,157 246,086
Superperformance I......................... 14,445 2.8% 14.29 January 1, 2011 129,819 328,816
Superperformance II........................ 24,549 11.3% 14.29 January 1, 2011 220,622 558,809
Richard M. Whiting
Time....................................... 5,166 1.4% 14.29 January 1, 2011 46,427 117,594
Performance................................ 3,928 1.1% 14.29 January 1, 2011 35,305 89,422
Superperformance I......................... 5,412 1.0% 14.29 January 1, 2011 48,641 123,202
Superperformance II........................ 8,189 3.8% 14.29 January 1, 2011 73,591 186,397
Roger B. Walcott, Jr.
Time....................................... 5,166 1.4% 14.29 January 1, 2011 46,427 117,594
Performance................................ 3,928 1.1% 14.29 January 1, 2011 35,305 89,422
Superperformance I......................... 5,412 1.0% 14.29 January 1, 2011 48,641 123,202
Superperformance II........................ 8,189 3.8% 14.29 January 1, 2011 73,591 186,397
Richard A. Navarre
Time....................................... 11,519 3.1% 14.29 January 1, 2011 103,523 262,212
Performance................................ 10,437 3.0% 14.29 January 1, 2011 93,797 237,577
Superperformance I......................... 18,963 3.7% 14.29 January 1, 2011 170,420 431,655
Superperformance II........................ 14,165 6.5% 14.29 January 1, 2011 127,303 322,442
Paul H. Vining
Time....................................... 14,000 3.8% 14.29 July 1, 2010 125,818 318,682
Performance................................ 14,000 4.0% 14.29 July 1, 2010 125,818 318,682
Superperformance I......................... 21,001 4.1% 14.29 July 1, 2010 188,740 478,055
Superperformance II........................ 14,000 6.4% 14.29 July 1, 2010 125,818 318,682
Time....................................... 19,166 5.2% 14.29 January 1, 2011 172,245 436,276
Performance................................ 17,928 5.1% 14.29 January 1, 2011 161,123 408,104
Superperformance I......................... 26,414 5.1% 14.29 January 1, 2011 237,381 601,257
Superperformance II........................ 22,189 10.2% 14.29 January 1, 2011 199,409 505,079
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The following table sets forth the number and value of securities
underlying unexercised options held by each of our executive officers listed on
the Summary Compensation Table above as of March 31, 2001. None of our executive
officers exercised any options in fiscal year 2001, and we do not have any stock
appreciation rights.
AGGREGATED OPTION/SAR EXERCISES IN FISCAL YEAR 2001 AND
OPTIONS/SAR VALUES AS OF MARCH 31, 2001
NUMBER OF SECURITIES
UNDERLYING UNEXERCISED VALUE OF UNEXERCISED
OPTION/SARS AS OF IN-THE-MONEY OPTIONS/SARS
MARCH 31, 2001 AS OF MARCH 31, 2001
SHARES VALUE -------------------------- ---------------------------
ACQUIRED IN REALIZED EXERCISABLE UNEXERCISABLE EXERCISABLE UNEXERCISABLE
NAME EXERCISE (#) ($) (#) (#) ($) ($)
---------------------------------------- ------------- ---------- ----------- ------------- ------------ -------------
Irl F. Engelhardt....................... -- -- 123,200 640,616 $1,073,072 $5,579,765
Richard M. Whiting...................... -- -- 44,755 229,700 389,816 2,000,687
Roger B. Walcott, Jr.................... -- -- 44,755 229,700 389,816 2,000,687
Richard A. Navarre...................... -- -- 33,575 210,372 292,438 1,832,340
Paul H. Vining.......................... -- -- 16,394 258,165 142,792 2,248,617
PENSION BENEFITS
Our Salaried Employees Retirement Plan, or pension plan, is a "defined
benefit" plan. The pension plan provides a monthly annuity to salaried employees
when they retire. A salaried employee must have at least five years of service
to be vested in the pension plan. A full benefit is available to a retiree at
age 62. A retiree can begin receiving a benefit as early as age 55; however, a
4% reduction factor applies for each year a retiree receives a benefit prior to
age 62.
An individual's retirement benefit under the pension plan is equal to the
sum of (1) 1.112% of the highest average monthly earnings over 60 consecutive
months up to the "covered compensation limit" multiplied by the employee's years
of service, not to exceed 35 years, and (2) 1.5% of the average monthly earnings
over 60 consecutive months over the "covered compensation limit" multiplied by
the employee's years of service, not to exceed 35 years.
We announced in February 1999 that the pension plan would be phased out
beginning January 1, 2001. Certain transition benefits were introduced based on
the age and/or service of the employee at December 31, 2000: (1) employees age
50 or older will continue to accrue service at 100%; (2) employees between the
ages of 45 and 49 or under age 45 with 20 years or more of service will accrue
service at the rate of 50% for each year of service worked after December 31,
2000; and (3) employees under age 45 with less than 20 years of service will
have their pension benefits frozen. In all cases, final average earnings for
retirement plan purposes will be capped at December 31, 2000 levels.
The estimated annual pension benefits payable upon retirement at age 62,
the normal retirement age, for the Chief Executive Officer and the named
executive officers are as follows:
Irl F. Engelhardt...................................................... $490,008
Richard M. Whiting..................................................... 264,786
Roger B. Walcott, Jr................................................... 24,663
Richard A. Navarre..................................................... 37,993
Paul H. Vining......................................................... 61,170
We have two supplemental defined benefit retirement plans that provide
retirement benefits to executives whose pay exceeds legislative limits for
qualified defined benefit plans.
OTHER BENEFIT PLANS
In addition to the pension plan, we maintain various other benefit plans
covering employees and retirees, including medical insurance plans and the
Employee Retirement Account, a defined contribution plan. We announced in
February 1999 that we were restructuring several of these plans over the
succeeding four years. The benefits associated with the medical insurance plan
and the Employee Retirement Account will be affected most significantly.
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The changes to the medical insurance plan include the following as of
January 1, 2000: (1) a decrease in employee and retiree contributions from 15%
to 10% of actual plan costs; (2) an increase in medical contributions for
dependents from 15% to 30% of actual plan costs; (3) a decrease in medical
coverage from 100% to 80% for specified expenses; (4) additional medical plan
options; and (5) changes to dependent eligibility rules for retirees. In
addition, the medical insurance plan was restructured so that employees leaving
us after January 1, 2003 (at age 55 or older with ten years of service) will be
covered under a medical premium reimbursement plan instead of the current
medical insurance plan.
Beginning with fiscal year 2000, a performance contribution feature was
added to the Employee Retirement Account to allow for our contributions of up to
a maximum of 4% of employees' salaries based upon meeting specified company
performance targets. Effective January 1, 2001, we increased our matching
contributions for the Employee Retirement Accounts to 100% of the first 3% of
base pay and 75% of the next 4% of base pay contributed by employee
participants. With the completion of the initial public offering in May 2001,
employees are now able to purchase shares of our stock through the Employee
Retirement Account. We have one defined contribution supplemental plan, which
provides benefits to executives whose pay exceeds legislative limits for
qualified defined contribution plans.
EMPLOYEE STOCK PURCHASE PLAN
In connection with the completion of the Company's initial public offering,
we adopted an employee stock purchase plan. One million five hundred thousand
shares of common stock will be available for purchase. Eligible full-time and
part-time employees will be able to contribute up to 15% of their base
compensation into this plan subject to a limit of $25,000 per year. These
employees will be able to purchase the shares at a 15% discount to the lower of
the fair market values of the initial and ending dates of each offering period.
There will be two offering periods each year, one commencing on April 1 (except
that the first offering period will commence on the effective date of the plan)
and the other commencing on October 1. Participating employees will be
restricted from selling their shares for 18 months from the purchase date,
except upon the death of a participant or a change in control of our company.
MANAGEMENT ANNUAL INCENTIVE COMPENSATION PLAN
We have an annual incentive compensation plan that provides a cash bonus to
selected employees based on the participant's base salary, target level and the
attainment of certain company and individual targets. The company targets are
established each year by the compensation committee of our board of directors or
the board of directors based on performance criteria that may include total
shareholder return, various return measures, earnings per share, EBITDA, cash
flow or other appropriate organizational and individual measures. The annual
incentive awards are designed to be exempt from the $1 million limit on
deductible compensation under section 162(m) of the Internal Revenue Code.
EMPLOYMENT AGREEMENTS
We have entered into employment agreements with Mr. Engelhardt, our
Chairman and Chief Executive Officer, or CEO, and Messrs. Whiting, Walcott,
Navarre, Vining and other key executive officers. The CEO's employment agreement
provides for a three-year term that extends day-to-day so that there is at all
times a remaining term of three years, and other executives' employment
agreements have a one-year term or a two-year term, each of which extends
day-to-day so that there is at all times a remaining term of one or two years,
respectively. Following a termination without cause or resignation for good
reason, the CEO is entitled to a lump sum payment equal to three years' base
salary and three times the higher of his (A) target annual bonus or (B) average
of the actual annual bonuses paid in the three prior years. The CEO is also
entitled to a one-time prorated bonus for the year of termination (based on our
actual performance multiplied by a fraction, the numerator of which is the
number of business days the CEO was employed during the year of termination, and
the denominator of which is the total number of business days during that year),
payable when bonuses, if any, are paid to our other executives. He will also
receive qualified and nonqualified pension, life insurance, medical and other
benefits for three years. The other key executives are entitled to the following
benefits, payable in equal installments over one or two years: (1) one or two
times base salary and (2) one or two times the higher of (A) the target annual
bonus or (B) the average of the actual annual bonuses paid in the three prior
years. In addition, the other executives are entitled to (1) a one-time prorated
bonus for the year of termination (based on our actual performance multiplied by
a fraction, the numerator of which is the number of business days the executive
was employed during the year of termination and the denominator of which is the
total number of business days during that year), payable when bonuses, if any,
are paid to our other executives; and (2) qualified and nonqualified pension,
life insurance, medical and other benefits for the one or two-year period, as
applicable, following termination. However, we are not obligated to provide any
benefits under tax qualified plans that are not permitted by the terms of each
plan or by applicable law or that could jeopardize the plan's tax status.
Continuing benefit coverage will terminate to the extent an executive (including
the CEO) is offered or obtains comparable coverage from any other employer. The
employment agreements provide for confidentiality during and following
employment, and include a noncompetition and
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nonsolicitation agreement that is effective during and for one year following
employment. If an executive (including the CEO) breaches any of his or her
confidentiality, noncompetition or nonsolicitation agreements, the executive
will forfeit any unpaid amounts or benefits. To the extent that excise taxes are
incurred by an executive (including the CEO) as a result of "excess parachute
payments," we will pay additional amounts up to $10 million, in the aggregate so
that executives would be in the same financial condition as if the excise taxes
were not incurred.
STOCK PURCHASE AND OPTION PLAN
We adopted our 1998 Stock Purchase and Option Plan for Key Employees.
Pursuant to that plan, the executive officers and 17 other employees acquired,
in the aggregate, approximately 3% of our initial fully-diluted equity, which
was issued as Class B common stock in connection with our acquisition on May 19,
1998. With respect to these shares, we provided a full recourse loan for the
amount of the tax liability to each executive, with a five-year principal
balloon payment that accelerates six months following any termination of
employment or disposition of the stock, with interest payable throughout the
term of the loan at the applicable federal rate. Executives who received Class B
common stock and some other employees were eligible to receive options under the
plan exercisable for common stock to purchase an aggregate of 7% of our initial
fully-diluted equity, or 2,819,460 shares. As of March 31, 2001, options to
purchase 1,296,950 shares were outstanding as "time options" in the form of
Incentive Stock Options (as defined in Section 422 of the Internal Revenue Code)
to the extent permitted under the Internal Revenue Code, and in the form of
non-qualified stock options for the remainder, and 1,301,290 options to purchase
shares were outstanding in the form of nonqualified stock options as
"performance options." Time options become exercisable with respect to 20% of
the shares subject to those options on each of the first five anniversaries of
May 19 of the fiscal year during which the options were granted if the
executive's employment continues through and includes that date. Time options
will become fully exercisable early upon death, disability, a change of control
or a recapitalization event. Performance options became exercisable early upon
our initial public offering. "Change of control," for the purposes of this plan,
means an acquisition of all or substantially all of our direct and indirect
assets by merger, consolidation, recapitalization event, stock or asset sale or
otherwise, immediately following which (a) Lehman Brothers and its affiliates
own, in the aggregate, less than 50% of our outstanding voting securities that
Lehman Brothers and its affiliates owned after May 19, 1998, excluding the sale
of $80 million of their original investment, which occurred after May 19, 1998,
or (b) any person individually owns more of our then-outstanding voting
securities than Lehman Brothers and its affiliates. "Recapitalization event,"
for purposes of this plan, means a recapitalization, reorganization, stock
dividend or other special corporate restructuring which results in an
extraordinary distribution to the stockholders of cash and/or securities through
the use of leveraging or otherwise but that does not result in a change of
control. "Initial public offering," for purposes of this plan, means the first
sale of shares of our stock to the public pursuant to an effective registration
statement filed under the Securities Act that results in the listing on a
national exchange or the NASDAQ National Market of the lesser of 25% of our
outstanding common stock and an aggregate value of outstanding securities equal
to $250.0 million.
The plan also provides for the grant of additional performance-based
options as "superperformance options" exercisable for common stock to purchase
an aggregate of another 7% of our initial fully-diluted equity, or 2,819,460
shares. As of March 31, 2001, options to purchase 2,627,269 shares were
outstanding as "superperformance options." Approximately 36% of these options
became exercisable upon our initial public offering and the remainder of these
options will vest in accordance with the achievement of specified financial
performance targets.
All options have an exercise price of $14.29 per share of our common stock.
All options under the plan have a ten-year term. Exercisable options expire
earlier, as follows: (1) upon termination for cause or a resignation without
good reason, immediately upon termination, (2) upon termination without cause,
resignation for good reason, death, disability or retirement, one year after
termination of employment or (3) if the option exercise price is higher than the
fair market value of our shares upon any termination of employment, immediately
upon termination. Unexercisable options terminate earlier upon any termination
of employment unless acceleration in connection with the termination, subject to
specified exceptions. Upon a change of control, the board of directors may
terminate the options so long as the executives are cashed out at the change of
control price or are permitted to exercise their options prior to the change of
control, except as otherwise provided.
LONG-TERM EQUITY INCENTIVE PLAN
In connection with the completion of the Company's initial public offering,
we adopted the Long-Term Equity Incentive Plan. Under that plan, selected
executive officers, key employees and other service providers will be eligible
to receive grants of stock options, shares of our common stock or monetary
payments based on the value of our stock or based upon the achievement of
specified performance goals. This plan is intended to provide an incentive for
employees to contribute to our success and align the interests of key employees
with the interests of our shareholders. Two million five hundred thousand shares
of our outstanding
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common stock will be available for issuing awards with a grant of up to
one-third of the total in fiscal year 2002. Awards may include stock
appreciation rights, restricted stock, performance awards, incentive stock
options, nonqualified stock options and stock units. Performance criteria for
the vesting of performance awards may include total shareholder return, various
return measures, earnings per share, EBITDA, cash flow or other appropriate
measures. The compensation committee of our board of directors or the board of
directors will determine performance goals and levels of rewards to be granted
upon the achievement of these goals. If we change the number of issued shares of
our common stock without new consideration, the total number of shares reserved
for issuance under this plan and the number of shares covered by each
outstanding award will be adjusted so that the aggregate consideration payable
to us, if any, and the value of each award will not be changed. Awards are
designed to be exempt from the $1 million limit on deductible compensation under
section 162(m) of the Internal Revenue Code.
EQUITY INCENTIVE PLAN FOR NON-EMPLOYEE DIRECTORS
In connection with the completion of the Company's initial public offering,
we adopted the Equity Incentive Plan for Non-Employee Directors. Under that
plan, members of our board of directors who are not employees of our company or
one of our affiliates will be eligible to receive grants of restricted stock and
options to purchase our stock at a price equal to the fair market value per
share of the stock on the date the option is granted. Restricted stock will be
granted to a director upon election or appointment to the board of directors,
and will vest upon the third anniversary of the date of grant. Options to
purchase stock will be granted to eligible directors each year at the annual
meeting of the board of directors, and will vest ratably over three years. All
options granted under the plan will expire after ten years from the date of the
grant, subject to earlier termination in connection with a director's
termination of service. Options to purchase stock granted under the plan will
become fully exercisable and restricted stock will become fully vested upon a
change of control, or upon the director's involuntary termination other than for
cause, voluntary termination with the board of director's consent, or permanent
disability. Options will remain exercisable for a period ending upon the earlier
to occur of five years after the director's involuntary termination without
cause or voluntary termination with the board of director's consent, or ten
years from the date of grant. In the event of a director's death while serving
on the board of directors, each of the outstanding options of the option holder
shall become exercisable immediately and may be exercised within a period of
five years after death, but no later than the expiration date of the option
term. If an option holder dies or becomes permanently disabled within five years
following termination of service on the board of directors, the option will be
exercisable for the longer of two years after the holder's death or five years
after termination of service on the board of directors, or until the earlier
expiration of the term of the option. Shares of restricted stock and options
will be forfeited upon the director's voluntary termination without consent of
the board of directors or termination for cause.
COMPENSATION OF DIRECTORS
Currently, members of our board of directors are not compensated for their
services; however, they are reimbursed for expenses.
COMPENSATION COMMITTEE INTERLOCKS AND INSIDER PARTICIPATION
None of our executive officers has served as a director or member of the
compensation committee, or other committee serving an equivalent function, of
any entity of which an executive officer is expected to serve as a member of our
compensation committee.
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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.
The following table sets forth information concerning ownership of our
capital stock as of May 31, 2001 by persons who beneficially own more than 5% of
the outstanding shares of capital stock, each person who is a director of our
company, each person who is a named executive officer, and all directors and
executive officers as a group. As of May 31, 2001, there were 51,892,456 shares
of common stock outstanding.
NAME AND ADDRESS OF BENEFICIAL OWNER AS OF MAY 31, 2001
------------------------------------ -----------------------
SHARES(1) PERCENT
---------- --------
Lehman Brothers Merchant Banking Partners II L.P. and affiliates
c/o Lehman Brothers Holdings Inc.
3 World Financial Center, 200 Vesey Street
New York, NY 10285.......................................................................... 29,400,000 56.7%
Co-Investment Partners, L.P.
c/o Lexington Partners Inc.
660 Madison Avenue, 23rd Floor
New York, NY 10021.......................................................................... 3,500,000 6.7
Irl F. Engelhardt.............................................................................. 638,464(2) 1.2
Roger B. Walcott, Jr........................................................................... 225,838(2) 0.4
Richard M. Whiting............................................................................. 225,338(2) 0.4
Paul H. Vining................................................................................. 213,318(2) 0.4
Richard A. Navarre............................................................................. 194,768(2) 0.4
Roger H. Goodspeed(3).......................................................................... -- --
Henry E. Lentz(3).............................................................................. -- --
Alan H. Washkowitz(3).......................................................................... -- --
All executives and directors as a group (11 people)............................................ 1,806,071 3.4%
--------------
(1) Beneficial ownership is determined in accordance with the rules of the SEC
and includes voting and investment power with respect to shares. Unless
otherwise indicated, the persons named in the table have sole voting and
sole investment control with respect to all shares beneficially owned.
(2) Includes options exercisable within 60 days after May 31, 2001.
(3) Messrs. Goodspeed, Lentz and Washkowitz are Managing Directors of Lehman
Brothers. Mr. Washkowitz is the head of Lehman Brothers Merchant Banking
and Mr. Lentz is a principal of Lehman Brothers Merchant Banking. Messrs.
Goodspeed, Lentz and Washkowitz disclaim beneficial ownership of the shares
held or controlled by these entities or their affiliates.
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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
TRANSACTIONS WITH AFFILIATES OF LEHMAN BROTHERS
Lehman Brothers served as our financial advisor in connection with the sale
of Citizens Power, which we completed in fiscal year 2001. We paid Lehman
Brothers a fee of approximately $1.5 million, plus reimbursement of expenses,
for those services.
Lehman Brothers served as one of our financial advisors in connection with
the sale of our Australian operations, which we completed on January 29, 2001.
We paid Lehman Brothers a fee of $2.7 million, plus reimbursement of expenses,
for those services.
After completion of the Company's initial public offering, Lehman Brothers
Merchant Banking Partners II L.P. and its affiliates (collectively, the "Lehman
Brothers Merchant Banking Fund") owns 57% of our common stock. Messrs.
Goodspeed, Lentz and Washkowitz, each one of our directors, are investors in the
Lehman Brothers Merchant Banking Fund and employees of Lehman Brothers.
TRANSACTIONS WITH MANAGEMENT
During fiscal years 1999, 2000 and 2001 some of our executive officers and
18 other employees purchased or were granted shares of our Class B common stock
under the 1998 Stock Purchase and Option Plan for Key Employees. In connection
with these purchases and grants, we, affiliates of Lehman Brothers Holdings and
the executives who received our Class B common stock entered into stockholders
agreements providing for certain rights of the investors relating to the
registration of their shares with respect to certain sales of our capital stock
by affiliates of Lehman Brothers Holdings. The stockholders agreements provide
the investors with the right to register and sell their unregistered stock in
the event that we conduct certain types of registered offerings.
In conjunction with the purchases and grants of our Class B common stock,
the executive officers and employees executed term notes. The term notes related
to these grants are due on May 19, 2003 and the term notes executed for
purchases are due on February 1, 2006. All of the term notes bear annual
interest at an applicable U.S. federal rate used by the Internal Revenue Service
for loans to employees. The maturity of the promissory notes will accelerate
upon the occurrence of certain events, including six months following any
termination of employment or disposition of the stock.
The following table indicates the amounts due under the term notes for our
executive officers with aggregate indebtedness in excess of $60,000 during the
year ended March 31, 2001:
LARGEST AGGREGATE
INDEBTEDNESS
DURING FISCAL YEAR ENDED OUTSTANDING INDEBTEDNESS AT
NAME MARCH 31, 2001 MARCH 31, 2001
---- -------------- --------------
Irl F. Engelhardt................................................ $ 661,503 $ 652,858
Richard M. Whiting............................................... 220,542 217,608
Roger B. Walcott, Jr............................................. 225,381 216,256
Richard A. Navarre............................................... 185,345 183,119
Paul H. Vining................................................... 213,193 213,193
Jeffery L. Klinger............................................... 130,169 128,728
Sharon D. Fiehler................................................ 128,724 128,724
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PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K.
(a) Documents filed as part of this Report
(1) Financial Statements.
The following financial statements of Peabody Energy Corporation are
included in Item 8 at the page indicated:
Page
----
Report of Independent Auditors 42
Audited Financial Statements:
Statements of Operations - Years ended March 31, 2001 and 2000, period from
May 20, 1998 to March 31, 1999, and period from April 1, 1998 to May 19, 1998 43
Balance Sheets - March 31, 2001 and 2000 44
Statements of Cash Flows - Years ended March 31, 2001 and 2000, period from
May 20, 1998 to March 31, 1999, and period from April 1, 1998 to May 19, 1998 45
Statements of Changes in Stockholders' Equity/Invested Capital - Years ended
March 31, 2001 and 2000, period from May 20, 1998 to March 31, 1999, and
period from April 1, 1998 to May 19, 1998 47
Notes to Financial Statements 48
(2) Financial Statement Schedule.
The following financial statement schedule of Peabody Energy Corporation is
included in Item 14, along with the report of independent auditors thereon,
at the pages indicated:
Page
----
Report of Independent Auditors on Financial Statement Schedule F-1
Valuation and Qualifying Accounts F-2
All other schedules for which provision is made in the applicable
accounting regulation of the Securities and Exchange Commission are not
required under the related instructions or are inapplicable and, therefore,
have been omitted.
(3) Exhibits.
See Exhibit Index hereto.
(b) Reports on Form 8-K.
We filed no reports on Form 8-K during the quarter ended March 31, 2001.
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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized.
PEABODY ENERGY CORPORATION
IRL F. ENGELHARDT
------------------------------------
Irl F. Engelhardt
Chairman and Chief Executive Officer
Date: June 27, 2001
Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following persons, on behalf of the registrant and
in the capacities and on the dates indicated.
SIGNATURE TITLE DATE
--------- ----- ----
IRL F. ENGELHARDT
------------------------------------ June 27, 2001
Irl F. Engelhardt Chairman, Chief Executive Officer and Director
(principal executive officer)
*
------------------------------------ June 27, 2001
Richard M. Whiting President, Chief Operating Officer and Director
RICHARD A. NAVARRE
------------------------------------ June 27, 2001
Richard A. Navarre Executive Vice President and Chief Financial Officer
(principal financial and accounting officer)
*
------------------------------------ June 27, 2001
Henry E. Lentz Vice President, Assistant Secretary and Director
*
------------------------------------ June 27, 2001
Roger H. Goodspeed Director
*
------------------------------------ June 27, 2001
Alan H. Washkowitz Director
*By: RICHARD A. NAVARRE
-------------------------------
Richard A. Navarre
Attorney-In-Fact
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EXHIBIT INDEX
The exhibits below are numbered in accordance with the Exhibit Table of Item 601
of Regulation S-K.
Exhibit
No. Description of Exhibit
------- ----------------------
3.1 Third Amended and Restated Certificate of Incorporation of the
Registrant (Incorporated by reference to Exhibit 3.1 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
3.2 Amended and restated By-Laws of the Registrant (Incorporated by
reference to Exhibit 3.2 of the Company's Form S-1
Registration Statement No. 333-55412).
4.1 Senior Note Indenture dated as of May 18, 1998 between the
Registrant and State Street Bank and Trust Company, as Senior
Note Trustee (Incorporated by reference to Exhibit 4.1 of the
Registrant's Form S-4 Registration Statement No. 333-59073).
4.2 Senior Subordinated Note Indenture dated as of May 18, 1998
between the Registrant and State Street Bank and Trust
Company, as Senior Subordinated Note Trustee (Incorporated by
reference to Exhibit 4.2 of the Registrant's Form S-4
Registration Statement No. 333-59073).
4.3 First Supplemental Senior Note Indenture dated as of May 19,
1998 among the Guaranteeing Subsidiary (as defined therein),
the Registrant the other Senior Note Guarantors (as defined in
the Senior Note Indenture) and State Street Bank and Trust
Company, as Senior Note Trustee (Incorporated by reference to
Exhibit 4.3 of the Registrant's Form S-4 Registration
Statement No. 333-59073).
4.4 First Supplemental Senior Subordinated Note Indenture dated as
of May 19, 1998 among the Guaranteeing Subsidiary (as defined
therein), the Registrant, the other Senior Subordinated Note
Guarantors (as defined in the Senior Subordinated Note
Indenture) and State Street Bank and Trust Company, as Senior
Subordinated Note Trustee (Incorporated by reference to
Exhibit 4.4 of the Registrant's Form S-4 Registration
Statement No. 333-59073).
4.5 Notation of Senior Subsidiary Guarantee dated as of May 19,
1998 among the Senior Note Guarantors (as defined in the
Senior Note Indenture) (Incorporated by reference to Exhibit
4.5 of the Registrant's Form S-4 Registration Statement No.
333-59073).
4.6 Notation of Subordinated Subsidiary Guarantee dated as of May
19, 1998 among the Senior Subordinated Note Guarantors (as
defined in the Senior Subordinated Note Indenture)
(Incorporated by reference to Exhibit 4.6 of the Registrant's
Form S-4 Registration Statement No. 333-59073).
4.7 Senior Note Registration Rights Agreement dated as of May 18, 1998
between the Registrant and Lehman Brothers Inc. (Incorporated
by reference to Exhibit 4.7 of the Registrant's Form S-4
Registration Statement No. 333-59073).
4.8 Senior Subordinated Note Registration Rights Agreement dated as of
May 18, 1998 between the Registrant and Lehman Brothers Inc.
(Incorporated by reference to Exhibit 4.8 of the Registrant's
Form S-4 Registration Statement No. 333-59073).
4.9 Second Supplemental Senior Note Indenture dated as of December
31, 1998 among the Guaranteeing Subsidiary (as defined
therein), the Registrant, the other Senior Note Guarantors (as
defined in the Senior Note Indenture) and State Street Bank
and Trust Company, as Senior Note Trustee (Incorporated by
reference to Exhibit 4.9 of the Registrant's Form 10-Q for the
quarter ended December 31, 1999).
4.10 Second Supplemental Senior Subordinated Note Indenture dated
as of December 31, 1998 among the Guaranteeing Subsidiary (as
defined therein), the Registrant, the other Senior
Subordinated Note Guarantors (as defined in the Senior
Subordinated Note Indenture) and State Street Bank and Trust
Company, as Senior Subordinated Note Trustee (Incorporated by
reference to Exhibit 4.10 of the Registrant's Form 10-Q for
the quarter ended December 31, 1999).
4.11 Third Supplemental Senior Note Indenture dated as of June 30,
1999 among the Guaranteeing Subsidiary (as defined therein),
the Registrant, the other Senior Note Guarantors (as defined
in the Senior Note Indenture) and State Street Bank and Trust
Company, as Senior Note Trustee (Incorporated by reference to
Exhibit 4.11 of the Registrant's Form 10-Q for the quarter
ended December 31, 1999).
4.12 Third Supplemental Senior Subordinated Note Indenture dated as
of June 30, 1999 among the Guaranteeing Subsidiary (as defined
therein), the Registrant, the other Senior Subordinated Note
Guarantors (as defined in the Senior Subordinated Note
Indenture) and State Street Bank and Trust Company, as Senior
Subordinated Note Trustee (Incorporated by reference to
Exhibit 4.12 of the Registrant's Form 10-Q for the quarter
ended December 31, 1999).
100
101
Exhibit
No. Description of Exhibit
------- ----------------------
10.1 Amended and Restated Credit Agreement dated as of June 9, 1998
among the Registrant, as Borrower, Lehman Brothers Inc., as
Arranger, Lehman Commercial Paper Inc., as Syndication Agent,
Documentation Agent, and Administrative Agent, and the lenders
party thereto (Incorporated by reference to Exhibit 10.1 of
the Registrant's Form S-4 Registration Statement No.
333-59073).
10.2 Guarantee and Collateral Agreement dated as of May 14, 1997 made
by the Guarantors, in favor of Lehman Commercial Paper, Inc.,
as Administrative Agent for the banks and other financial
institutions (Incorporated by reference to Exhibit 10.2 of the
Registrant's Form S-4 Registration Statement No. 333-59073).
10.3 Federal Coal Lease WYW0321779: North Antelope/Rochelle Mine
(Incorporated by reference to Exhibit 10.3 of the Registrant's
Form S-4 Registration Statement No. 333-59073).
10.4 Federal Coal Lease WYW119554: North Antelope/Rochelle Mine
(Incorporated by reference to Exhibit 10.4 of the Registrant's
Form S-4 Registration Statement No. 333-59073).
10.5 Federal Coal Lease WYW5036: Rawhide Mine (Incorporated by
reference to Exhibit 10.5 of the Registrant's Form S-4
Registration Statement No. 333-59073).
10.6 Federal Coal Lease WYW3397: Caballo Mine (Incorporated by
reference to Exhibit 10.6 of the Registrant's Form S-4
Registration Statement No. 333-59073).
10.7 Federal Coal Lease WYW83394: Caballo Mine (Incorporated by
reference to Exhibit 10.7 of the Registrant's Form S-4
Registration Statement No. 333-59073).
10.8 Federal Coal Lease WYW136142 (Incorporated by reference to Exhibit
10.7 of Amendment No. 1 of the Registrant's Form S-4
Registration Statement No. 333-59073).
10.9 Royalty Prepayment Agreement by and among Peabody Natural
Resources Company, Gallo Finance Company and Chaco Energy
Company, dated September 30, 1998 (Incorporated by reference
to Exhibit 10.9 of the Registrant's Form 10-Q for the second
quarter ended September 30, 1998).
10.10* 1998 Stock Purchase and Option Plan for Key Employees of the
Registrant (Incorporated by reference to Exhibit 10.10 of the
Registrant's Form 10-Q for the third quarter ended December
1998).
10.11* Employment Agreement between Irl F. Engelhardt and the Registrant
dated May 19, 1998 (Incorporated by reference to Exhibit 10.11
of the Registrant's Form S-1 Registration Statement No.
333-55412).
10.12* Employment Agreement between Richard M. Whiting and the Registrant
dated May 19, 1998 (Incorporated by reference to Exhibit 10.12
of the Registrant's Form S-1 Registration Statement No.
333-55412).
10.13* Employment Agreement between Richard A. Navarre and the Registrant
dated May 19, 1998 (Incorporated by reference to Exhibit 10.13
of the Registrant's Form S-1 Registration Statement No.
333-55412).
10.14* Employment Agreement between Roger B. Walcott, Jr. and the
Registrant dated May 19, 1998 (Incorporated by reference to
Exhibit 10.14 of the Registrant's Form S-1 Registration
Statement No. 333-55412).
10.15 Receivables Sale Agreement dated as of March 31, 2000, by and
among Originators and the Registrant (Incorporated by
reference to Exhibit 10.16 of the Registrant's Form 10-K for
the year ended March 31, 2000).
10.16 Receivables Contribution Agreement dated as of March 31, 2000,
by and between the Registrant and P&L Receivables Company, LLC
("Seller") (Incorporated by reference to Exhibit 10.17 of the
Registrant's Form 10-K for the year ended March 31, 2000).
10.17 Receivables Purchase Agreement as of March 31, 2000, by and
among Seller, the Registrant, International Securitization
Corporation, Bank One, NA, as Agent ("Agent") and the
Financial Institutions named therein (Incorporated by
reference to Exhibit 10.18 of the Registrant's Form 10-K for
the year ended March 31, 2000).
10.18* Employment Agreement between Paul H. Vining and the Registrant
dated July 1, 2000 (Incorporated by reference to Exhibit 10.19
of the Registrant's Form S-1 Registration Statement No.
333-55412).
10.19 Amendment No. 1 to Credit Agreement dated as of April 30, 2001
among the Registrant, as Borrower, Lehman Brothers Inc., as
Arranger, Lehman Commercial Paper Inc., as Syndication Agent,
Bank of America National Trust & Savings Association and The
Fuji Bank, Limited, as Documentation Agents, Bank One, NA, as
Administrative Agent, and the lenders party thereto
(Incorporated by reference to Exhibit 10.20 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
101
102
Exhibit
No. Description of Exhibit
------- ----------------------
10.20* First Amendment to the Employment Agreement between Irl F.
Engelhardt and the Registrant dated as of May 10, 2001
(Incorporated by reference to Exhibit 10.21 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
10.21* First Amendment to the Employment Agreement between Richard M.
Whiting and the Registrant dated as of May 10, 2001
(Incorporated by reference to Exhibit 10.22 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
10.22* First Amendment to the Employment Agreement between Richard A.
Navarre and the Registrant dated as of May 10, 2001
(Incorporated by reference to Exhibit 10.23 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
10.23* First Amendment to the Employment Agreement between Roger B.
Walcott, Jr. and the Registrant dated as of May 10, 2001
(Incorporated by reference to Exhibit 10.24 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
10.24* First Amendment to the Employment Agreement between Paul H.
Vining and the Registrant dated as of May 10, 2001
(Incorporated by reference to Exhibit 10.25 of the
Registrant's Form S-1 Registration Statement No. 333-55412).
10.25* Form of First Amendment to Stockholders' Agreement dated as of
May 19, 1998.
10.26* Long-Term Equity Incentive Plan.
10.27* 2001 Employee Stock Purchase Plan.
10.28* Equity Incentive Plan for Non-Employee Directors.
10.29* Form of Amendment to the Non-Qualified Stock Option Agreement.
21 List of Subsidiaries.
23 Consent of Ernst & Young LLP, Independent Auditors.
24 Power of Attorney.
* These exhibits constitute all management contracts, compensatory plans and
arrangements required to be filed as an exhibit to this form pursuant to
Item 14(c) of this report.
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REPORT OF INDEPENDENT AUDITORS
Board of Directors
Peabody Energy Corporation
We have audited the consolidated financial statements of Peabody Energy
Corporation (the Company), formerly P&L Coal Holdings Corporation, as of March
31, 2001 and 2000, and for the years then ended and the period from May 20, 1998
to March 31, 1999, and the combined financial statements of P&L Coal Group (the
Predecessor Company) for the period from April 1, 1998 to May 19, 1998 and have
issued our report thereon dated April 20, 2001. Our audits also included the
financial statement schedule listed in Item 14(a). This schedule is the
responsibility of Company's management. Our responsibility is to express an
opinion based on our audits. In our opinion the financial statement schedule
referred to above, when considered in relation to the basic financial statements
taken as a whole, presents fairly in all material respects the information set
forth therein.
/s/ Ernst & Young LLP
St. Louis, Missouri
April 20, 2001
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104
PEABODY ENERGY CORPORATION
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
(In thousands) Balance at Charged to Balance at
Beginning Costs and End
Description of Period Expenses Deductions(1) Other of Period
------------------------------------------------ ---------- ---------- ------------- ------------- -----------
YEAR ENDED MARCH 31, 2001
Reserves deducted from asset accounts:
Land and coal interests $ 13,199 $ 605 $ -- $ (620)(2) $ 13,184
Reserve for materials and supplies 12,400 -- (2,672) 1,834 (2) 11,562
Allowance for doubtful accounts 1,233 -- (20) -- 1,213
YEAR ENDED MARCH 31, 2000
Reserves deducted from asset accounts:
Land and coal interests $ 54,277 $ 2,179 $(40,541) $ (2,716)(2) $ 13,199
(5)
Reserve for materials and supplies 16,558 -- (4,748) 590 (2) 12,400
Allowance for doubtful accounts 177 1,213 (157) -- 1,233
MAY 20, 1998 TO MARCH 31, 1999
Reserves deducted from asset accounts:
Land and coal interests $ 51,455 $ 3,138 $ (316) $ -- $ 54,277
Reserve for materials and supplies 6,087 -- (1,037) 11,508 (3) 16,558
Allowance for doubtful accounts 9,073 -- (8,980) 84 (4) 177
-------------------------------------------------------------------------------------------------------------------------------
(PREDECESSOR COMPANY)
APRIL 1, 1998 TO MAY 19, 1998
Reserves deducted from asset accounts:
Land and coal interests $ 67,884 $ 124 $ (10) $ (16,543)(2) $ 51,455
Reserve for materials and supplies 6,316 -- (229) -- 6,087
Allowance for doubtful accounts 9,100 -- (27) -- 9,073
(1) Reserves utilized, unless otherwise indicated.
(2) Balances transferred from other accounts.
(3) Balances recorded as part of May 19, 1998 purchase accounting adjustments.
(4) Balances acquired as part of the controlling interest in Black Beauty Coal
Company purchased January 1, 1999.
(5) Balances transferred as part of asset contribution to joint venture.
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