UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2003
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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
- --------------------------------------- ------------------------------
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
701 MARKET STREET, ST. LOUIS, MISSOURI 63101-1826
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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)
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. X Yes No
--- ---
Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act). X Yes No
--- ---
Number of shares outstanding of each of the Registrant's classes of Common
Stock, as of October 20, 2003: Common Stock, par value $0.01 per share,
54,239,150 shares outstanding.
INDEX
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements Page
----
Unaudited Condensed Consolidated Statements of Operations for the Quarters and
Nine Months Ended September 30, 2003 and 2002..................................... 2
Condensed Consolidated Balance Sheets as of September 30, 2003 (unaudited) and
December 31, 2002................................................................. 3
Unaudited Condensed Consolidated Statements of Cash Flows for the Nine Months
Ended September 30, 2003 and 2002................................................. 4
Notes to Unaudited Condensed Consolidated Financial Statements.................... 5
Item 2. Management's Discussion and Analysis of Financial Condition and Results of
Operations........................................................................ 24
Item 3. Quantitative and Qualitative Disclosures About Market Risk........................ 32
Item 4. Controls and Procedures........................................................... 33
PART II. OTHER INFORMATION
Item 1. Legal Proceedings................................................................. 33
Item 6. Exhibits and Reports on Form 8-K.................................................. 34
PART I -- FINANCIAL INFORMATION
Item 1. Financial Statements.
PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except share and per share information)
Quarter Ended Nine Months Ended
September 30, September 30,
2003 2002 2003 2002
------------ ------------ ------------ ------------
REVENUES
Sales $ 682,034 $ 688,967 $ 2,010,825 $ 1,967,541
Other revenues 19,921 25,644 65,669 79,776
------------ ------------ ------------ ------------
Total revenues 701,955 714,611 2,076,494 2,047,317
COSTS AND EXPENSES
Operating costs and expenses 578,997 579,449 1,725,620 1,640,670
Depreciation, depletion and amortization 61,224 59,099 176,789 176,415
Asset retirement obligation expense 7,542 -- 20,633 --
Selling and administrative expenses 22,590 25,132 76,416 72,193
Net gain on property and equipment disposals (3,987) (389) (23,376) (3,475)
------------ ------------ ------------ ------------
OPERATING PROFIT 35,589 51,320 100,412 161,514
Interest expense 22,347 25,813 77,391 76,754
Early debt extinguishment costs -- -- 53,513 --
Interest income (371) (5,535) (2,549) (6,603)
------------ ------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES
AND MINORITY INTERESTS 13,613 31,042 (27,943) 91,363
Income tax provision (benefit) (8,598) (1,465) (49,621) 4,568
Minority interests 693 3,471 2,401 10,948
------------ ------------ ------------ ------------
INCOME BEFORE ACCOUNTING CHANGES 21,518 29,036 19,277 75,847
Cumulative effect of accounting changes, net of taxes -- -- (10,144) --
------------ ------------ ------------ ------------
NET INCOME $ 21,518 $ 29,036 $ 9,133 $ 75,847
============ ============ ============ ============
BASIC EARNINGS PER COMMON SHARE:
Income before accounting changes $ 0.40 $ 0.56 $ 0.36 $ 1.46
Cumulative effect of accounting changes, net of taxes -- -- (0.19) --
------------ ------------ ------------ ------------
Net income $ 0.40 $ 0.56 $ 0.17 $ 1.46
============ ============ ============ ============
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING 54,002,659 52,176,646 53,062,052 52,106,359
============ ============ ============ ============
DILUTED EARNINGS PER COMMON SHARE:
Income before accounting changes $ 0.39 $ 0.54 $ 0.35 $ 1.41
Cumulative effect of accounting changes, net of taxes -- -- (0.18) --
------------ ------------ ------------ ------------
Net income $ 0.39 $ 0.54 $ 0.17 $ 1.41
============ ============ ============ ============
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING 55,225,879 53,649,383 54,540,603 53,777,145
============ ============ ============ ============
DIVIDENDS DECLARED PER SHARE $ 0.125 $ 0.10 $ 0.325 $ 0.30
============ ============ ============ ============
See accompanying notes to unaudited condensed consolidated financial statements.
2
PEABODY ENERGY CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except share and per share information)
(Unaudited)
September 30, 2003 December 31, 2002
------------------ -----------------
ASSETS
Current assets
Cash and cash equivalents $ 105,829 $ 71,210
Accounts receivable, less allowance for doubtful accounts of $1,361
at September 30, 2003 and $1,331 at December 31, 2002 154,082 153,212
Materials and supplies 43,029 39,416
Coal inventory 202,795 190,272
Assets from coal trading activities 43,664 69,898
Deferred income taxes 10,750 10,361
Other current assets 23,019 15,554
----------- -----------
Total current assets 583,168 549,923
Property, plant, equipment and mine development, net of accumulated depreciation,
depletion and amortization of $998,307 at September 30, 2003 and $858,187
at December 31, 2002 4,290,103 4,273,042
Investments and other assets 332,768 317,212
----------- -----------
Total assets $ 5,206,039 $ 5,140,177
=========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Short-term borrowings and current maturities of long-term debt $ 20,031 $ 47,515
Liabilities from coal trading activities 24,084 37,008
Accounts payable and accrued expenses 551,889 547,013
----------- -----------
Total current liabilities 596,004 631,536
Long-term debt, less current maturities 1,180,666 981,696
Deferred income taxes 438,056 499,310
Asset retirement obligations 382,757 386,777
Workers' compensation obligations 213,499 209,798
Accrued postretirement benefit costs 958,271 959,599
Obligation to industry fund 46,278 49,760
Other noncurrent liabilities 294,621 303,442
----------- -----------
Total liabilities 4,110,152 4,021,918
Minority interests 1,398 37,121
Stockholders' equity
Preferred Stock - $0.01 per share par value; 10,000,000
shares authorized, no shares issued or outstanding
as of September 30, 2003 or December 31, 2002 -- --
Series Common Stock - $0.01 per share par value; 40,000,000
shares authorized, no shares issued or outstanding
as of September 30, 2003 or December 31, 2002 -- --
Common Stock - $0.01 per share par value; 150,000,000 shares authorized,
54,360,140 shares issued and 54,235,611 shares outstanding as
of September 30, 2003 and 150,000,000 shares authorized, 52,417,483 shares
issued and 52,400,278 shares outstanding as of December 31, 2002 543 524
Additional paid-in capital 988,729 958,567
Retained earnings 192,730 200,859
Employee stock loans (30) (1,142)
Accumulated other comprehensive loss (83,830) (77,627)
Treasury shares, at cost: 124,529 shares and 17,205 shares as of
September 30, 2003 and December 31, 2002, respectively (3,653) (43)
----------- -----------
Total stockholders' equity 1,094,489 1,081,138
----------- -----------
Total liabilities and stockholders' equity $ 5,206,039 $ 5,140,177
=========== ===========
See accompanying notes to unaudited condensed consolidated financial statements.
3
PEABODY ENERGY CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
Nine Months Ended
September 30,
------------------------------
2003 2002
----------- -----------
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 9,133 $ 75,847
Cumulative effect of accounting changes, net of taxes 10,144 --
----------- -----------
Income before accounting changes 19,277 75,847
Adjustments to reconcile income before accounting changes to
net cash provided by operating activities:
Depreciation, depletion and amortization 176,789 176,415
Deferred income taxes (50,428) 2,741
Early debt extinguishment costs 53,513 --
Amortization of debt discount and debt issuance costs 5,935 7,400
Net gain on property and equipment disposals (23,376) (3,475)
Minority interests 2,401 10,948
Changes in current assets and liabilities:
Accounts receivable (4,470) 13,121
Materials and supplies (3,613) (327)
Coal inventory (12,523) (14,101)
Net assets from coal trading activities (20,334) (16,339)
Other current assets (6,561) (3,956)
Accounts payable and accrued expenses 7,713 (24,309)
Asset retirement obligations (10,192) (4,075)
Workers' compensation obligations 3,701 (331)
Accrued postretirement benefit costs 165 (137)
Obligation to industry fund (3,482) (5,866)
Other, net (18,737) (4,962)
----------- -----------
Net cash provided by operating activities 115,778 208,594
----------- -----------
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to property, plant, equipment and mine development (118,817) (161,332)
Additions to advance mining royalties (7,706) (8,052)
Acquisitions, net (90,000) (45,537)
Investments in joint ventures (1,400) (475)
Proceeds from property and equipment disposals 34,722 16,521
----------- -----------
Net cash used in investing activities (183,201) (198,875)
----------- -----------
CASH FLOWS FROM FINANCING ACTIVITIES
Net change in revolving lines of credit (121,584) 6,492
Proceeds from long-term debt 1,102,735 --
Payments of long-term debt (866,134) (17,976)
Increase of securitized interests in accounts receivable 3,600 --
Payment of debt issuance costs (23,632) --
Distributions to minority interests (4,063) (7,868)
Dividends paid (17,262) (15,632)
Proceeds from stock options exercised 24,599 1,239
Other 2,849 1,262
----------- -----------
Net cash provided by (used in) financing activities 101,108 (32,483)
----------- -----------
Effect of exchange rate changes on cash and cash equivalents 934 22
Net increase (decrease) in cash and cash equivalents 34,619 (22,742)
Cash and cash equivalents at beginning of year 71,210 38,622
----------- -----------
Cash and cash equivalents at end of period $ 105,829 $ 15,880
=========== ===========
See accompanying notes to unaudited condensed consolidated financial statements.
4
PEABODY ENERGY CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2003
(1) BASIS OF PRESENTATION
The condensed consolidated financial statements include the accounts of
Peabody Energy Corporation (the "Company") and its controlled affiliates. All
significant intercompany transactions, profits and balances have been eliminated
in consolidation. Certain prior year amounts have been reclassified to conform
with the current year presentation.
The accompanying condensed consolidated financial statements as of
September 30, 2003 and for the quarters and nine months ended September 30, 2003
and 2002, and the notes thereto, are unaudited. However, in the opinion of
management, these financial statements reflect all normal, recurring adjustments
necessary for a fair presentation of the results of the periods presented. The
balance sheet information as of December 31, 2002 has been derived from the
Company's audited consolidated balance sheet. The results of operations for the
quarter and nine months ended September 30, 2003 are not necessarily indicative
of the results to be expected for future quarters or for the year ending
December 31, 2003.
(2) LONG-TERM DEBT
During March 2003, the Company entered into a series of transactions,
discussed in detail below, to refinance a substantial portion of its outstanding
indebtedness. The refinancing expanded the Company's revolving line of credit
capacity and lowered its overall borrowing costs. The Company's total
indebtedness (in thousands) consisted of the following at:
September 30, 2003 December 31, 2002
------------------ -----------------
Term Loan under Senior Secured Credit Facility $ 447,750 $ --
6.875% Senior Notes due 2013 650,000 --
Fair value of interest rate swaps - 6.875% Senior Notes 7,285 --
9.625% Senior Subordinated Notes redeemed in 2003 -- 391,490
8.875% Senior Notes redeemed in 2003 -- 316,498
5.0% Subordinated Note 78,273 85,055
Senior unsecured notes under various agreements -- 58,214
Unsecured revolving credit agreement -- 116,584
Other 17,389 61,370
------------------ -----------------
$ 1,200,697 $ 1,029,211
================== =================
The following table shows the sources and uses (in thousands) of cash related to
the refinancing transactions:
Sources:
Revolving Credit Facility $ --
Term Loan under Senior Secured Credit Facility 450,000
6.875% Senior Notes due 2013 650,000
----------
Total $1,100,000
==========
Uses:
Repayment of 9.625% Senior Subordinated Notes $ 392,219
Repayment of 8.875% Senior Notes 317,098
Repayment of Black Beauty indebtedness 203,215
Fees and prepayment premiums paid in connection with refinancing 63,667
Acquisition of 18.3% interest in Black Beauty Coal Company 90,000
Cash 33,801
----------
$1,100,000
==========
5
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
Use of Proceeds
The Company used the $1.1 billion of proceeds from the $450.0 million term
loan under its Senior Secured Credit Facility and the $650.0 million in 6.875%
Senior Notes primarily to repay and retire indebtedness. During March 2003, the
Company completed a tender offer to retire $134.0 million of its 9.625% Senior
Subordinated Notes and $109.1 million of its 8.875% Senior Notes. On May 15,
2003, the remaining $258.2 million of 9.625% Senior Subordinated Notes and
$208.0 million of 8.875% Senior Notes were redeemed. Early prepayment premiums
of $12.0 million were paid related to the tender offer and early prepayment
premiums of $21.7 million were paid in connection with the May 15, 2003
redemption. Also during March 2003, $203.2 million of Black Beauty indebtedness
was repaid, along with $6.3 million of related early prepayment premiums.
In addition to the retirement of the debt described above, the Company paid
$23.6 million in fees associated with issuing the new debt instruments. On April
7, 2003, the Company used $90.0 million to acquire the remaining 18.3% of Black
Beauty (see Note 4 below). The remaining cash of $33.8 million was primarily
used to pay accrued interest on the debt instruments that were repaid. The
Company's new debt instruments are described in greater detail below.
Senior Secured Credit Facility
On March 21, 2003, the Company entered into a new Senior Secured Credit
Facility that consists of a $600.0 million revolving credit facility and a
$450.0 million term loan. The new revolving credit facility, which currently
bears interest at LIBOR plus 2.0% and expires in March 2008, provides for
maximum borrowings and/or letters of credit of $600.0 million. The Company had
letters of credit outstanding under the facility of $241.0 million at September
30, 2003, leaving $359.0 million available for borrowing. The new $450.0 million
term loan currently bears interest at LIBOR plus 2.5%. The applicable rate was
3.64% as of September 30, 2003. Principal of $4.5 million per year, which is
paid in quarterly installments, is due through March 31, 2009. The remaining
principal of $423.0 million is due in quarterly installments of $105.8 million
to be paid from June 30, 2009 through March 31, 2010. The facility is secured by
the capital stock and certain assets of the Company's "restricted subsidiaries"
(as defined in the facility). These restricted subsidiaries are also guarantors
of the facility. Under the facility, the Company must comply with certain
financial covenants on a quarterly basis. These covenants include a minimum
EBITDA (as defined in the facility) interest coverage ratio, a maximum "total
obligations" (as defined in the facility) to EBITDA ratio and a maximum senior
secured debt to EBITDA ratio. The Company was in compliance with these covenants
as of September 30, 2003.
6.875% Senior Notes due March 2013
On March 21, 2003, the Company issued $650.0 million in senior notes, which
bear interest at 6.875% and are due in March 2013. The notes were initially sold
in accordance with Securities and Exchange Commission Rule 144A, and the Company
filed a registration statement in June 2003 with the Securities and Exchange
Commission that enabled the holders of the notes to exchange them for publicly
registered notes with substantially the same terms. The notes, which are
unsecured, are guaranteed by the Company's "restricted subsidiaries" as defined
in the note indenture. The note indenture contains covenants which, among other
things, limit the Company's ability to incur additional indebtedness and issue
preferred stock, pay dividends or make other distributions, make other
restricted payments and investments, create liens, sell assets and merge or
consolidate with other entities. The notes are redeemable prior to March 15,
2008 at a redemption price equal to 100% of the principal amount plus a
make-whole premium (as defined in the indenture) and on or after March 15, 2008
at fixed redemption prices as set forth in the indenture.
Early Debt Extinguishment Costs
In connection with the refinancing, the Company incurred early debt
extinguishment costs during the nine months ended September 30, 2003 of $53.5
million, comprised of the following:
- the excess of prepayment premiums over the carrying value of the debt
retired of $41.8 million;
- non-cash charges to write-off debt issuance costs associated with the
debt extinguished of $17.5 million; and
- a $5.8 million gain related to the termination and monetization of
interest rate swaps associated with the debt extinguished.
As a result of the adoption on January 1, 2003 of Statement of Financial
Accounting Standards ("SFAS") No. 145 "Rescission of FASB Statements No. 4, 44
and 64, Amendment of FASB Statement No. 13, and Technical Corrections," gains or
losses on debt extinguishment are presented as a component of results from
continuing operations unless the
6
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
extinguishment meets the criteria for classification as an extraordinary item in
Accounting Principles Board Opinion No. 30. The effect of the adoption and
application of this new standard was to decrease income before income taxes and
minority interests for the nine months ended September 30, 2003 by $53.5
million. Prior year results of operations included no early debt extinguishment
costs.
Interest Rate Swaps
In May 2003, the Company entered into and designated four interest rate
swaps with notional amounts totaling $100.0 million as a fair value hedge of our
6.875% Senior Notes. Under the swaps, the Company pays a floating rate that
resets each March 15 and September 15, based upon the six-month LIBOR rate, for
a period of ten years ending March 15, 2013 and receives a fixed rate of 6.875%.
The applicable floating rate was 4.25% as of September 30, 2003.
In September 2003, the Company entered into two $400.0 million interest
rate swaps. One $400.0 million notional amount floating-to-fixed interest rate
swap, expiring March 15, 2010, was designated as a hedge of changes in expected
cash flows on the term loan under the Senior Secured Credit Facility. Under this
swap, the Company pays a fixed rate of 6.764% and receives a floating rate of
LIBOR plus 2.5% (3.64% at September 30, 2003) that resets each March 15, June
15, September 15 and December 15 based upon the three-month LIBOR rate. Another
$400.0 million notional amount fixed-to-floating interest rate swap, expiring
March 15, 2013, was designated as a hedge of the changes in the fair value of
the 6.875% Senior Notes due 2013. Under this swap, the Company pays a floating
rate of LIBOR plus 1.97% (3.11% at September 30, 2003) that resets each March
15, June 15, September 15 and December 15 based upon the three-month LIBOR rate
and receives a fixed rate of 6.875%. The swaps will lower the Company's overall
borrowing costs on $400.0 million of debt principal by 0.64% over the term of
the floating-to-fixed swap.
Because the critical terms of the swaps and the respective debt instruments
they hedge coincide, there was no hedge ineffectiveness recognized in the
statement of operations during the nine months ended September 30, 2003. As of
September 30, 2003, the balance sheet reflects a net unrealized gain on the fair
value hedges discussed above of $7.3 million, which is reflected as an
adjustment to the carrying value of the Senior Notes (see table above). Related
to the cash flow hedge, the balance sheet at September 30, 2003 reflects a net
unrealized loss of $14.5 million, which is recognized net of a $5.8 million tax
benefit, in other comprehensive income (see Note 8).
(3) CUMULATIVE EFFECT OF ACCOUNTING CHANGES
On January 1, 2003, the Company adopted SFAS No. 143, "Accounting for Asset
Retirement Obligations," which addresses accounting and reporting for
obligations associated with the retirement of tangible long-lived assets and the
associated asset retirement costs.
For the Company, asset retirement obligation expense represents the
systematic accretion and depreciation of future mine reclamation costs, which
includes the costs to reclaim the land disturbed during the mining process and
the removal of mine facilities, equipment, transportation and other support
facilities.
SFAS No. 143 requires the fair value of a liability for an asset's
retirement obligation to be recorded in the period in which it is incurred if a
reasonable estimate of fair value can be made, and that the corresponding cost
is capitalized as part of the carrying amount of the related long-lived asset.
The liability is accreted to its then present value each period, and the
capitalized cost is depreciated over the useful life of the related asset. If
the liability is settled for an amount other than the recorded amount, a gain or
loss is recognized.
Under its previous accounting method, the Company accrued the estimated
future costs to reclaim the land as the acreage was disturbed at surface mine
operations and the estimated costs to reclaim support acreage and to perform
other related functions at both surface and underground mines ratably over the
lives of the mines.
Pursuant to the January 1, 2003 adoption of SFAS No. 143, the Company:
- recognized a credit to income during the first quarter of 2003 of
$9.1 million, net of tax, for the cumulative effect of the
accounting change;
- increased total liabilities by $0.5 million to record the asset
retirement obligations;
- increased property, plant and equipment by $12.1 million to add
the asset retirement costs to the carrying amount of our mine
properties and investments and other assets by $6.5 million to
reflect the incremental amount of reclamation obligations
recoverable from third parties; and
7
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
- increased accumulated depreciation, depletion and amortization by
$2.9 million for the amount of expense previously recognized.
Adopting SFAS No. 143 had no impact on the Company's reported cash flows.
The Company's reclamation liabilities are unfunded.
On October 25, 2002, the Emerging Issues Task Force (EITF) rescinded EITF
Issue No. 98-10 "Accounting for Contracts Involved in Energy Trading and Risk
Management Activities." As a result of the rescission, trading contracts entered
into prior to October 25, 2002 that did not meet the definition of a derivative
under SFAS No. 133, "Accounting for Derivative Instruments and Hedging
Activities" (as amended) were no longer accounted for on a fair value basis,
effective January 1, 2003. In the first quarter of 2003, the Company recorded a
cumulative effect charge in the statement of operations of $20.2 million, net of
income taxes, to reverse the unrealized gains and losses on non-derivative
energy trading contracts recorded prior to December 31, 2002.
Effective January 1, 2003, the Company changed its method of amortizing
actuarial gains and losses related to net periodic postretirement benefit costs.
The Company previously amortized actuarial gains and losses using a 5% corridor
with an amortization period of three years. Under the new method, the corridor
has been eliminated and all actuarial gains and losses are now amortized over
the average remaining service period of active plan participants, which is
currently estimated at 9.5 years. The Company considers this method preferable
in that the elimination of the corridor allows a closer approximation of the
fair value of the liability for postretirement benefit costs, and the
amortization of actuarial gains and losses over the average remaining service
period provides a better matching of the cost of the associated liability over
the working life of the active plan participants. As a result of this change,
the Company recognized a $0.9 million cumulative effect gain in the first
quarter of 2003.
The effect of the changes for the quarter and nine months ended September
30, 2003 was to increase income before accounting changes by $5.2 million, or
$0.09 per diluted share, net of income taxes and $17.4 million, or $0.32 per
diluted share, net of income taxes, respectively. The cumulative effect charge
of $10.1 million (net of income tax benefit of $6.8 million) to apply
retroactively the new methods described above was included in results of
operations for the nine months ended September 30, 2003. Below are pro forma net
income and earnings per share results for the Company assuming the new methods
had been retroactively applied (dollars in thousands, except per share data):
Quarter Ended Nine Months Ended
September 30, September 30,
-------------------------- --------------------------
2003 2002 2003 2002
---------- ----------- ---------- ----------
Net income:
As reported $ 21,518 $ 29,036 $ 9,133 $ 75,847
Pro forma 21,518 26,490 19,277 61,190
Basic earnings per share:
As reported $ 0.40 $ 0.56 $ 0.17 $ 1.46
Pro forma 0.40 0.51 0.36 1.17
Diluted earnings per share:
As reported $ 0.39 $ 0.54 $ 0.17 $ 1.41
Pro forma 0.39 0.49 0.35 1.14
(4) BUSINESS COMBINATIONS
On April 7, 2003, the Company purchased the remaining 18.3% of Black Beauty
Coal Company and affiliated entities not owned by it for $90.0 million and
contingent consideration. The additional consideration is contingent on Black
Beauty's achievement of certain levels of operating profit in 2003 and 2004, as
set forth in the purchase and sale agreement. As a result of the acquisition,
the Company now owns 100% of Black Beauty Coal Company. The acquisition was
accounted for as a purchase.
8
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
(5) COAL INVENTORY
Inventories consisted of the following (dollars in thousands) at:
September 30, December 31,
2003 2002
-------- --------
Raw coal $ 17,891 $ 13,935
Work in process 149,676 143,963
Saleable coal 35,228 32,374
-------- --------
Total $202,795 $190,272
======== ========
(6) ASSETS AND LIABILITIES FROM COAL TRADING ACTIVITIES
On October 25, 2002, the EITF rescinded EITF Issue No. 98-10 "Accounting
for Contracts Involved in Energy Trading and Risk Management Activities." As a
result of the rescission, trading contracts entered into prior to October 25,
2002 that did not meet the definition of a derivative under SFAS No. 133 (as
amended) were no longer accounted for on a fair value basis effective January 1,
2003. The Company recorded a cumulative effect charge of $20.2 million, net of
income taxes, effective January 1, 2003 to reverse the net unrealized gains on
non-derivative energy trading contracts recorded prior to December 31, 2002.
Substantially all of these non-derivative energy trading contracts will settle
in 2003 and 2004.
The fair value of coal trading derivatives as of September 30, 2003 are set
forth below (dollars in thousands):
Fair Value
-------------------------------
Assets Liabilities
----------- -----------
Forward contracts $ 43,631 $ 23,161
Option contracts 33 923
----------- -----------
Total $ 43,664 $ 24,084
=========== ===========
Ninety-nine percent of the contracts in the Company's trading portfolio as
of September 30, 2003 were valued utilizing prices from over-the-counter market
sources, adjusted for coal quality, and less than one percent of the Company's
contracts were valued based on similar market transactions.
As of September 30, 2003, the timing of the estimated future realization of
the value of the Company's trading portfolio was as follows:
Year of Percentage
Expiration of Portfolio
---------- ------------
2003 13%
2004 84%
2005 3%
---
100%
===
At September 30, 2003, 52% of the Company's credit exposure related to coal
trading activities was with counterparties that are investment grade. Where
practical, the Company takes steps to reduce its credit exposure to customers or
counterparties whose credit has deteriorated and who may pose a higher risk, as
determined by the Company's credit management function, of failure to perform
under their contractual obligations. These steps include obtaining letters of
credit or cash collateral, requiring prepayments for shipments or the creation
of customer trust accounts held for the
9
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
Company's benefit to fund the payments required under existing contracts. To
further reduce credit exposure in its trading business, the Company also seeks
to enter into netting agreements with counterparties that permit the Company to
offset receivables and payables with such counterparties.
The Company's coal trading operations traded 5.3 million tons and 10.6
million tons for the quarters ended September 30, 2003 and 2002, respectively,
and 28.7 million tons and 55.8 million tons for the nine months ended September
30, 2003 and 2002, respectively.
(7) EARNINGS PER SHARE AND STOCKHOLDERS' EQUITY
Weighted Average Shares Outstanding
A reconciliation of weighted average shares outstanding follows:
Quarter Ended September 30, Nine Months Ended September 30,
--------------------------- -------------------------------
2003 2002 2003 2002
----------- ----------- ----------- -----------
Weighted average shares outstanding - basic 54,002,659 52,176,646 53,062,052 52,106,359
Dilutive impact of stock options 1,223,220 1,472,737 1,478,551 1,670,786
----------- ----------- ----------- -----------
Weighted average shares outstanding - diluted 55,225,879 53,649,383 54,540,603 53,777,145
=========== =========== =========== ===========
Stock Compensation
These interim financial statements include the disclosure requirements of
SFAS No. 123, "Accounting for Stock-Based Compensation," as amended by SFAS No.
148, "Accounting for Stock-Based Compensation - Transition and Disclosure." The
Company applies Accounting Principles Board ("APB") Opinion No. 25 and related
interpretations in accounting for its equity incentive plans. The Company
recorded $0.1 million of compensation expense for granted stock options during
each of the quarters ended September 30, 2003 and 2002, and $0.2 million of
compensation expense for granted stock options during the nine months ended
September 30, 2003 and 2002. The following table reflects pro forma net income
and basic and diluted earnings 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 methodology set forth under SFAS
No. 123, "Accounting for Stock-Based Compensation"(in thousands, except per
share data):
Quarter Ended Nine Months Ended
September 30, September 30,
-------------------------- -------------------------
2003 2002 2003 2002
---------- --------- ---------- ----------
Net income:
As reported $ 21,518 $ 29,036 $ 9,133 $ 75,847
Pro forma 19,866 27,814 4,369 72,195
Basic earnings per share:
As reported $ 0.40 $ 0.56 $ 0.17 $ 1.46
Pro forma 0.37 0.53 0.08 1.39
Diluted earnings per share:
As reported $ 0.39 $ 0.54 $ 0.17 $ 1.41
Pro forma 0.36 0.52 0.08 1.34
Treasury Stock
During the nine months ended September 30, 2003, the Company received
107,324 shares of common stock as consideration for employees' exercise of stock
options. The value of the common stock tendered by employees to exercise stock
options was based upon the closing price on the dates of the respective
transactions. The common stock tenders were in accordance with the provisions of
the 1998 Stock Purchase and Option Plan, which was previously approved by the
Company's Board of Directors.
10
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
(8) COMPREHENSIVE INCOME
The following table sets forth the components of comprehensive income for
the quarters and nine months ended September 30, 2003 and 2002 (in thousands):
Quarter Ended Nine Months Ended
September 30, September 30,
---------------------- ----------------------
2003 2002 2003 2002
-------- -------- -------- --------
Net income $ 21,518 $ 29,036 $ 9,133 $ 75,847
Foreign currency translation adjustment (3,622) (2) 2,478 (2)
Cash flow hedge:
Comprehensive pre-tax loss from decrease
in fair value of cash flow hedge (14,469) -- (14,469) --
Income tax benefit 5,788 -- 5,788 --
-------- -------- -------- --------
Comprehensive income $ 9,215 $ 29,034 $ 2,930 $ 75,845
======== ======== ======== ========
(9) SEGMENT INFORMATION
The Company reports its operations primarily through the following
reportable operating segments: "U.S. Mining," "Trading and Brokerage," and
"Australian Mining" The principal business of the U.S. Mining segment is mining,
preparation and sale of its steam coal, sold primarily to electric utilities,
and metallurgical coal, sold to steel and coke producers. The Trading and
Brokerage segment's principal business is the marketing and trading of coal and
contract restructuring activities. The Australian Mining segment consists of the
operations of the Wilkie Creek Mine. This segment's principal business is the
same as the U.S. Mining Segment. "Corporate and Other" consists primarily of
corporate overhead not directly attributable to the U.S. Mining or Trading and
Brokerage operating segments, and resource management activities. In some cases,
the Company's brokerage operation acts as the sales agent for the U.S. Mining
and Australian Mining operations. For purposes of the presentation below,
intercompany sales between the mining operations and Trading and Brokerage
Operations have been eliminated, and the third party sales are reflected in the
mining operations' revenues.
The U.S. Mining segment results below also include costs related to past
mining activities and a portion of consolidated net gains on property disposals.
Past mining activities and net gains on property disposals are discussed
separately from U.S. Mining results in "Item 2. Management's Discussion and
Analysis of Financial Condition and Results of Operations."
11
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
Operating segment results for the quarters and nine months ended September
30, 2003 and 2002 are as follows (in thousands):
Quarter Ended Nine Months Ended
September 30, September 30,
----------------------------- -----------------------------
2003 2002 2003 2002
----------- ----------- ----------- -----------
Revenues:
U.S. Mining $ 622,311 $ 658,339 $ 1,793,970 $ 1,877,444
Trading and Brokerage 66,002 51,443 248,187 152,182
Australian Mining 7,746 1,435 20,594 1,435
Corporate and Other 5,896 3,394 13,743 16,256
----------- ----------- ----------- -----------
Total $ 701,955 $ 714,611 $ 2,076,494 $ 2,047,317
=========== =========== =========== ===========
Operating Profit:
U.S. Mining $ 39,078 $ 69,950 $ 105,560 $ 193,116
Trading and Brokerage 9,138 4,920 40,081 33,159
Australian Mining 2,374 357 1,554 357
Corporate and Other (15,001) (23,907) (46,783) (65,118)
----------- ----------- ----------- -----------
Total $ 35,589 $ 51,320 $ 100,412 $ 161,514
=========== =========== =========== ===========
A reconciliation of segment operating profit to consolidated income (loss)
before income taxes follows (in thousands):
Quarter Ended Nine Months Ended
September 30, September 30,
----------------------------- -----------------------------
2003 2002 2003 2002
----------- ----------- ----------- -----------
Total segment operating profit $ 35,589 $ 51,320 $ 100,412 $ 161,514
Interest expense 22,347 25,813 77,391 76,754
Early debt extinguishment costs -- -- 53,513 --
Interest income (371) (5,535) (2,549) (6,603)
Minority interests 693 3,471 2,401 10,948
----------- ----------- ----------- -----------
Income (loss) before income taxes $ 12,920 $ 27,571 $ (30,344) $ 80,415
=========== =========== =========== ===========
(10) COMMITMENTS AND CONTINGENCIES
Environmental
Environmental claims have been asserted against a subsidiary of the
Company, Gold Fields Mining Corporation ("Gold Fields"), at 22 sites in the
United States. Gold Fields is a dormant, non-coal producing entity that was
previously managed and owned by Hanson PLC, a predecessor owner of the Company.
In the February 1997 spin-off of its energy businesses, Hanson PLC combined Gold
Fields with the Company. These sites are related to activities of Gold Fields or
its former subsidiaries. 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 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
12
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
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 the estimation of
liabilities recorded on its consolidated balance sheets. The undiscounted
liabilities for environmental cleanup-related costs recorded as part of "Other
noncurrent liabilities" were $40.8 million and $42.1 million at September 30,
2003 and December 31, 2002, respectively. These amounts represent those costs
that the Company believes are probable and reasonably estimable.
Navajo Nation
On June 18, 1999, the Navajo Nation served the Company's subsidiaries,
Peabody Holding Company, Inc., Peabody Coal Company and Peabody Western Coal
Company ("Peabody Western"), with a complaint that had been filed in the U.S.
District Court for the District of Columbia. Other defendants in the litigation
are one customer, 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's two coal leases for the Kayenta
and Black Mesa mines have terminated due to Peabody Western's breach of these
leases and a reformation of the two coal leases to adjust the royalty rate to
20%. On March 15, 2001, the court allowed the Hopi Tribe to intervene in this
lawsuit. The Hopi Tribe has asserted seven claims including fraud and is seeking
various remedies including unspecified actual damages, punitive damages and
reformation of its coal lease.
On March 4, 2003, the U.S. Supreme Court issued a ruling in a companion
lawsuit involving the Navajo Nation and the United States. The Court rejected
the Navajo Nation's allegation that the U.S. breached its trust responsibilities
to the Tribe in approving the coal lease amendments and was liable for money
damages. On May 2, 2003, the Company's subsidiaries filed a renewed motion to
dismiss the Navajo Nation's lawsuit against them based on the Supreme Court's
decision.
While the outcome of litigation is subject to uncertainties, based on the
Company's preliminary evaluation of the issues and their potential impact on the
Company, the Company believes this matter will be resolved without a material
adverse effect on the Company's financial condition, results of operations or
cash flows.
Mohave Generating Station
Peabody Western has a long-term coal supply agreement with the owners of
the Mohave Generating Station that expires on December 31, 2005. There is a
dispute with the Hopi Tribe regarding the use of groundwater in the
transportation of the coal by pipeline to the Mohave plant. Southern California
Edison (the majority owner and operator of the plant) is involved in a
California Public Utilities Commission proceeding related to recovery of future
capital expenditures for new pollution abatement equipment for the station.
Alternatively, Southern California Edison has asked for authorization to spend
money for the shutdown of the Mohave plant. In a July 2003 filing with the
California Public Utilities Commission, the operator affirmed that the Mohave
plant is not forecast to return to service as a coal-fired resource until
mid-2009 at the earliest. The Company is in active discussions to resolve the
complex issues critical to the continuation of the operation of the Mohave
Generating Station and the renewal of the coal supply agreement after December
31, 2005. There is no assurance that the issues critical to the continued
operation of the Mohave plant will be resolved. If these issues are not resolved
in a timely manner, the operation of the Mohave plant will cease or be suspended
on December 31, 2005. The Mohave plant is the sole customer of the Black Mesa
Mine, which sold 4.6 million tons of coal in 2002. If the Company is unable to
renew the coal supply agreement with the Mohave Generating Station, our
financial condition and results of operations could be adversely affected after
2005.
Citizens Power
In connection with the August 2000 sale of the Company's former subsidiary,
Citizens Power LLC (Citizens Power), the Company has indemnified the buyer,
Edison Mission Energy, from certain losses resulting from specified power
contracts and guarantees. Other than those discussed below, there are no known
issues with any of the specified power contracts and guarantees.
13
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
During the period that Citizens Power was owned by the Company, Citizens
Power guaranteed the obligations of two affiliates to make payments to third
parties for power delivered under fixed-priced power sales agreements with terms
that extend through 2008. Edison Mission Energy has stated and the Company
believes there will be sufficient cash flow to pay the power suppliers, assuming
timely payment by the power purchasers. The power purchasers have made timely
payments to the Citizens Power affiliates and Edison Mission Energy has not made
a claim against the Company under the indemnity.
Also during the ownership period, a Citizens Power subsidiary, now called
Edison Mission Marketing & Trading ("EMMT"), entered into a power purchase
agreement to sell power in connection with a restructured power supply agreement
that runs through 2016. The Citizens Power subsidiary subsequently entered into
a power purchase agreement with NRG Power Marketing Inc. (NRG Power Marketing)
for the same term. NRG Power Marketing filed a Chapter 11 bankruptcy petition
and on August 6, 2003, NRG Power Marketing obtained bankruptcy court approval to
reject the power purchase agreement. The bankruptcy court also rejected EMMT's
request to file a complaint with FERC seeking an order limiting NRG Power
Marketing's ability to cease deliveries under the contract without FERC
approval. EMMT has appealed that bankruptcy court's decision. The NRG Power
Marketing power sales contract is one of the contracts covered by the indemnity
provision, but the Company indemnity does not apply to losses caused by the
negligent act or omission of EMMT, Edison Mission Energy or its affiliates. The
Company authorized EMMT to purchase power through March 31, 2004 to cap the
exposure of the Company during that time. NRG Power Marketing is no longer
delivering power to EMMT and the power is being supplied by EMMT as discussed
above. The Company is responsible for the incremental costs incurred by EMMT
related to the authorized power purchases; however, the Company does not believe
its exposure under the authorized power purchase agreement is material and has
reserved its rights against EMMT and Edison Mission Energy. The power supply
obtained by EMMT is sold to CL Power Sales 8 LLC ("CL8"), which sells power to
Central Maine Power ("CMP"). On November 4, 2003, CL8 and CMP executed documents
to restructure their power sales agreement for deliveries commencing in March
2005. CMP has sought Maine Public Utility Commission approval for the
restructuring. The Company believes the power sales agreement will be
restructured, which is expected to result in the termination in March 2005 of
EMMT's power sales obligation. Other steps are being taken to resolve the issues
surrounding EMMT's power sales obligation through March 2005.
Due to the length and specific requirements of the contracts covered by the
indemnity, the impact of the power purchase transactions and the uncertainty
surrounding the NRG Power Marketing situation, the Company cannot reasonably
estimate its exposure under the indemnity beyond March 31, 2004.
Other
Accounts receivable in the consolidated balance sheets as of September 30,
2003 and December 31, 2002 included $13.0 million and $8.6 million,
respectively, of receivables billed during 2001 through 2003 that have been
disputed by two customers who have withheld payment. The Company believes these
billings were made properly under the respective coal supply agreements with
each customer. The Company is in arbitration and litigation with these customers
to resolve this issue, and believes the receivables to be fully collectible.
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 September 30, 2003, purchase commitments for capital expenditures were
approximately $67.7 million.
(11) SECONDARY OFFERINGS
On May 7, 2003, certain shareholders of the Company, including the
Company's largest shareholder, Lehman Brothers Merchant Banking Partners II L.P.
and affiliates, sold 5,750,000 shares of common stock, including sales under an
over-allotment option of 750,000 shares. The selling shareholders received all
net proceeds. The Company did not sell any shares through the offering. Lehman
Brothers Merchant Banking Partners II L.P. and affiliates sold, in the
aggregate, 5,617,825 shares in the offering, and their beneficial ownership of
the Company declined from 41% to 29%.
On August 4, 2003, the Company's largest shareholder, Lehman Brothers
Merchant Banking Partners II L.P. and affiliates, sold 5,400,000 shares of
common stock. Lehman Brothers Merchant Banking Partners II L.P. and affiliates
received all net proceeds. The Company did not sell any shares through the
offering. Lehman Brothers Merchant Banking Partners II L.P. and affiliates'
beneficial ownership of the Company declined from 29% to 19%.
14
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
(12) RELATED PARTY TRANSACTIONS
Lehman Brothers Inc. is an affiliate of Lehman Brothers Merchant Banking
Partners II L.P. As discussed in Note 2 above, the Company refinanced a
substantial portion of its indebtedness by entering into a new Senior Secured
Credit Facility and issuing new Senior Notes. Based upon a competitive bidding
process conducted by members of management and reviewed by members of the
Company's Board of Directors not affiliated with Lehman Brothers Inc., the
Company appointed Wachovia Securities, Inc., Fleet Securities, Inc. and Lehman
Brothers Inc. as lead arrangers for the Senior Secured Credit Facility, and
Lehman Brothers Inc. and Morgan Stanley as joint book running managers for the
Senior Notes. Lehman Brothers Inc. received total fees of $7.4 million for their
services in connection with the refinancing; such fees were consistent with the
fees paid to other parties to the transaction for their respective services.
In May 2003 and July 2003, Lehman Brothers Inc. served as the lead
underwriter in connection with the secondary offerings discussed in Note 12
below, and fees for their services were paid by the selling shareholders and not
by the Company. The Company paid incidental expenses customarily incurred by a
registering company in connection with the secondary offerings.
As discussed in Note 2 above and in the "Liquidity and Capital Resources"
section of Part I, Item 2 of this report, in May 2003 the Company entered into
four $25.0 million fixed to floating interest rate swaps as a hedge of the
changes in fair value of the 6.875% Senior Notes due 2013. Lehman Brothers Inc.
was chosen as one of the swap counterparties as part of a competitive bidding
process among eight financial institutions.
(13) SUBSEQUENT EVENT
The Company filed a shelf registration statement on Form S-3 with the
Securities and Exchange Commission on October 22, 2003. Under the registration
statement, the Company may offer and sell from time to time unsecured debt
securities consisting of notes, debentures, and other debt securities; common
stock; preferred stock; warrants; and/or units totaling a maximum of $1.25
billion. Related proceeds would be used for general corporate purposes including
repayment of other debt, capital expenditures, possible acquisitions and any
other purposes that may be stated in any prospectus supplement.
In addition, under the registration statement, Lehman Brothers Merchant
Banking Partners II L.P. and affiliates may offer up to 10.3 million shares of
the Company's common stock through transactions that may include underwritten
offerings. If the Lehman Brothers Merchant Banking Partners II L.P. and
affiliates offer and sell the maximum shares under this registration statement,
this would complete their planned exit strategy to return the investment to its
partners over time.
15
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
(14) SUPPLEMENTAL GUARANTOR/NON-GUARANTOR FINANCIAL INFORMATION
In accordance with the indentures governing the 6.875% Senior Notes,
certain wholly-owned U.S. subsidiaries of the Company have fully and
unconditionally guaranteed the 6.875% Senior 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 the holders of the 6.875% Senior Notes. The
following unaudited condensed historical financial statement information is
provided for the Guarantor/Non-Guarantor Subsidiaries. After the Company's
acquisition on April 7, 2003 of the remaining 18.3% of Black Beauty, this
subsidiary became a Guarantor subsidiary of the 6.875% Senior Notes. Prior year
amounts have been reclassified to conform with the current year presentation.
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
QUARTER ENDED SEPTEMBER 30, 2003
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Eliminations Consolidated
------------ ------------ ------------ ------------ ------------
Total revenues $ -- $ 680,974 $ 35,910 $ (14,929) $ 701,955
Costs and expenses
Operating costs and expenses -- 563,582 30,344 (14,929) 578,997
Depreciation, depletion and amortization -- 60,354 870 -- 61,224
Asset retirement obligation expense -- 7,480 62 -- 7,542
Selling and administrative expenses 130 21,952 508 -- 22,590
Net gain on property and equipment
disposals -- (3,864) (123) -- (3,987)
Interest expense 32,797 30,605 521 (41,576) 22,347
Interest income (20,866) (17,346) (3,735) 41,576 (371)
--------- --------- --------- --------- ---------
Income (loss) before income taxes and
minority interests (12,061) 18,211 7,463 -- 13,613
Income tax provision (benefit) (9,957) 2,400 (1,041) -- (8,598)
Minority interests -- 693 -- -- 693
--------- --------- --------- --------- ---------
Net income (loss) $ (2,104) $ 15,118 $ 8,504 $ -- $ 21,518
========= ========= ========= ========= =========
16
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
QUARTER ENDED SEPTEMBER 30, 2002
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Eliminations Consolidated
------------ ------------ ------------ ------------ ------------
Total revenues $ -- $ 691,713 $ 38,423 $ (15,525) $ 714,611
Costs and expenses
Operating costs and expenses -- 562,710 32,264 (15,525) 579,449
Depreciation, depletion and amortization -- 58,375 724 -- 59,099
Selling and administrative expenses 71 24,046 1,015 -- 25,132
Net gain on property and equipment
disposals -- (280) (109) -- (389)
Interest expense 34,678 27,798 953 (37,616) 25,813
Interest income (17,139) (22,068) (3,944) 37,616 (5,535)
--------- --------- --------- --------- ---------
Income (loss) before income taxes and
minority interests (17,610) 41,132 7,520 -- 31,042
Income tax provision (benefit) 947 (2,156) (256) -- (1,465)
Minority interests -- 3,471 -- -- 3,471
--------- --------- --------- --------- ---------
Net income (loss) $ (18,557) $ 39,817 $ 7,776 $ -- $ 29,036
========= ========= ========= ========= =========
17
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
NINE MONTHS ENDED SEPTEMBER 30, 2003
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Eliminations Consolidated
------------ ------------ ------------ ------------ ------------
Total revenues $ -- $ 1,998,070 $ 123,176 $ (44,752) $ 2,076,494
Costs and expenses
Operating costs and expenses -- 1,660,050 110,322 (44,752) 1,725,620
Depreciation, depletion and amortization -- 174,091 2,698 -- 176,789
Asset retirement obligation expense -- 20,447 186 -- 20,633
Selling and administrative expenses 492 74,261 1,663 -- 76,416
Net gain on property and equipment
disposals -- (23,264) (112) -- (23,376)
Interest expense 107,253 88,775 1,981 (120,618) 77,391
Early debt extinguishment costs 46,164 7,349 -- -- 53,513
Interest income (60,081) (52,257) (10,829) 120,618 (2,549)
----------- ----------- ----------- ----------- -----------
Income (loss) before income taxes and
minority interests (93,828) 48,618 17,267 -- (27,943)
Income tax provision (benefit) (51,328) 721 986 -- (49,621)
Minority interests -- 2,401 -- -- 2,401
Cumulative effect of accounting changes,
net of taxes 6,762 (16,349) (557) -- (10,144)
----------- ----------- ----------- ----------- -----------
Net income (loss) $ (35,738) $ 29,147 $ 15,724 $ -- $ 9,133
=========== =========== =========== =========== ===========
18
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
NINE MONTHS ENDED SEPTEMBER 30, 2002
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Eliminations Consolidated
------------ ------------ ------------ ------------ ------------
Total revenues $ -- $ 1,988,100 $ 105,126 $ (45,909) $ 2,047,317
Costs and expenses
Operating costs and expenses -- 1,597,563 89,016 (45,909) 1,640,670
Depreciation, depletion and amortization -- 174,267 2,148 -- 176,415
Selling and administrative expenses 340 69,789 2,064 -- 72,193
Net gain on property and equipment
disposals -- (3,378) (97) -- (3,475)
Interest expense 103,394 82,811 2,801 (112,252) 76,754
Interest income (51,437) (56,249) (11,169) 112,252 (6,603)
--------- ----------- ----------- ---------- ----------
Income (loss) before income taxes and
minority interests (52,297) 123,297 20,363 -- 91,363
Income tax provision (benefit) (2,522) 6,013 1,077 -- 4,568
Minority interests -- 10,948 -- -- 10,948
--------- ----------- ----------- ----------- -----------
Net income (loss) $ (49,775) $ 106,336 $ 19,286 $ -- $ 75,847
========= =========== =========== =========== ===========
19
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED BALANCE SHEETS
SEPTEMBER 30, 2003
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Eliminations Consolidated
------------ ------------ ------------ ------------ ------------
ASSETS
Current assets
Cash and cash equivalents $ 100,205 $ 1,313 $ 4,311 $ -- $ 105,829
Accounts receivable 52 126,005 28,025 -- 154,082
Inventories -- 242,488 3,336 -- 245,824
Assets from coal trading activities -- 43,664 -- -- 43,664
Deferred income taxes -- 10,101 649 -- 10,750
Other current assets 66 19,589 3,364 -- 23,019
------------ ------------ ------------ ------------ ------------
Total current assets 100,323 443,160 39,685 -- 583,168
Property, plant, equipment and mine
development, at cost -- 5,229,649 58,761 -- 5,288,410
Less accumulated depreciation,
depletion and amortization -- (979,588) (18,719) -- (998,307)
------------ ------------ ------------ ------------ ------------
Property, plant, equipment and
mine development, net -- 4,250,061 40,042 -- 4,290,103
Investments and other assets 3,540,298 218,432 2,567 (3,428,529) 332,768
------------ ------------ ------------ ------------ ------------
Total assets $ 3,640,621 $ 4,911,653 $ 82,294 $(3,428,529) $ 5,206,039
============ ============ ============ ============ ============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Short-term borrowings and current
maturities of long-term debt $ 4,500 $ 13,568 $ 1,963 $ -- $ 20,031
Payables and notes payable to affiliates, net 1,359,749 (1,371,479) 11,730 -- --
Liabilities from coal trading activities -- 23,631 453 -- 24,084
Accounts payable and accrued expenses 4,064 537,989 9,836 -- 551,889
------------ ------------ ------------ ------------ ------------
Total current liabilities 1,368,313 (796,291) 23,982 -- 596,004
Long-term debt, less current maturities 1,100,535 76,578 3,553 -- 1,180,666
Deferred income taxes -- 432,349 5,707 -- 438,056
Other noncurrent liabilities 7,923 1,882,693 4,810 -- 1,895,426
------------ ------------ ------------ ------------ ------------
Total liabilities 2,476,771 1,595,329 38,052 -- 4,110,152
Minority interests -- 1,398 -- -- 1,398
Stockholders' equity 1,163,850 3,314,926 44,242 (3,428,529) 1,094,489
------------ ------------ ------------ ------------ ------------
Total liabilities and stockholders'
equity $ 3,640,621 $ 4,911,653 $ 82,294 $(3,428,529) $ 5,206,039
============ ============ ============ ============ ============
20
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
SUPPLEMENTAL CONDENSED CONSOLIDATED BALANCE SHEETS
DECEMBER 31, 2002
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Eliminations Consolidated
------------ ------------ ------------ -------------- ------------
ASSETS
Current assets
Cash and cash equivalents $ 60,666 $ 5,365 $ 5,179 $ -- $ 71,210
Accounts receivable 836 102,917 49,459 -- 153,212
Inventories -- 227,075 2,613 -- 229,688
Assets from coal trading activities -- 69,898 -- -- 69,898
Deferred income taxes -- 10,101 260 -- 10,361
Other current assets 260 12,039 3,255 -- 15,554
------------ ------------ ------------ -------------- ------------
Total current assets 61,762 427,395 60,766 -- 549,923
Property, plant, equipment and mine
development, at cost -- 5,079,997 51,232 -- 5,131,229
Less accumulated depreciation, depletion
and amortization -- (841,781) (16,406) -- (858,187)
------------ ------------ ------------ -------------- ------------
Property, plant, equipment and mine
development, net -- 4,238,216 34,826 -- 4,273,042
Investments and other assets 3,448,319 279,216 17,835 (3,428,158) 317,212
------------ ------------ ------------ -------------- ------------
Total assets $ 3,510,081 $ 4,944,827 $ 113,427 $(3,428,158) $ 5,140,177
============ ============ ============ ============== ============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Short-term borrowings and current
maturities of long-term debt $ -- $ 44,441 $ 3,074 $ -- $ 47,515
Payables and notes payable to affiliates, net 1,626,695 (1,643,593) 16,898 -- --
Liabilities from coal trading activities -- 37,008 -- -- 37,008
Accounts payable and accrued expenses 9,427 521,917 15,669 -- 547,013
------------ ------------ ------------ -------------- ------------
Total current liabilities 1,636,122 (1,040,227) 35,641 -- 631,536
Long-term debt, less current maturities 714,571 263,826 3,299 -- 981,696
Deferred income taxes -- 495,284 4,026 -- 499,310
Other noncurrent liabilities 623 1,906,050 2,703 -- 1,909,376
------------ ------------ ------------ -------------- ------------
Total liabilities 2,351,316 1,624,933 45,669 -- 4,021,918
Minority interests -- 37,121 -- -- 37,121
Stockholders' equity 1,158,765 3,282,773 67,758 (3,428,158) 1,081,138
------------ ------------ ------------ -------------- ------------
Total liabilities and stockholders'
equity $ 3,510,081 $ 4,944,827 $ 113,427 $(3,428,158) $ 5,140,177
============ ============ ============ ============== ============
21
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
NINE MONTHS ENDED SEPTEMBER 30, 2003
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Consolidated
------------ ------------ ------------ --------------
Net cash provided by (used in) operating activities $ (56,273) $ 150,841 $ 21,210 $ 115,778
------------ ------------ ------------ --------------
Additions to property, plant, equipment and
mine development -- (114,962) (3,855) (118,817)
Additions to advance mining royalties -- (7,706) -- (7,706)
Acquisition, net -- (90,000) -- (90,000)
Investment in joint venture -- (1,400) -- (1,400)
Proceeds from property and equipment disposals -- 34,063 659 34,722
------------ ------------ ------------ --------------
Net cash used in investing activities -- (180,005) (3,196) (183,201)
------------ ------------ ------------ --------------
Net change in revolving lines of credit -- (121,584) -- (121,584)
Proceeds from long-term debt 1,100,000 2,735 -- 1,102,735
Payments of long-term debt (745,259) (120,345) (530) (866,134)
Increase of securitized interests in accounts receivable -- -- 3,600 3,600
Payment of debt issuance costs (23,632) -- -- (23,632)
Distributions to minority interests -- (4,063) -- (4,063)
Dividends paid (17,262) -- -- (17,262)
Proceeds from stock options exercised 24,599 -- -- 24,599
Transactions with affiliates, net (245,483) 268,369 (22,886) --
Other 2,849 -- -- 2,849
------------ ------------ ------------ --------------
Net cash provided by (used in) financing activities 95,812 25,112 (19,816) 101,108
------------ ------------ ------------ --------------
Effect of exchange rate changes on cash and equivalents -- -- 934 934
Net increase (decrease) in cash and cash equivalents 39,539 (4,052) (868) 34,619
Cash and cash equivalents at beginning of period 60,666 5,365 5,179 71,210
------------ ------------ ------------ --------------
Cash and cash equivalents at end of period $ 100,205 $ 1,313 $ 4,311 $ 105,829
============ ============ ============ ==============
22
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS, continued
PEABODY ENERGY CORPORATION
UNAUDITED SUPPLEMENTAL CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
NINE MONTHS ENDED SEPTEMBER 30, 2002
(In thousands)
Parent Guarantor Non-Guarantor
Company Subsidiaries Subsidiaries Consolidated
------------ ------------ ------------ --------------
Net cash provided by (used in) operating activities $ (49,420) $ 231,177 $ 26,837 $ 208,594
------------ ------------ ------------ --------------
Additions to property, plant, equipment and
mine development -- (158,083) (3,249) (161,332)
Additions to advance mining royalties -- (8,052) -- (8,052)
Acquisitions, net -- (45,537) -- (45,537)
Investment in joint venture -- (475) -- (475)
Proceeds from property and equipment disposals -- 15,760 761 16,521
------------ ------------ ------------ --------------
Net cash used in investing activities -- (196,387) (2,488) (198,875)
------------ ------------ ------------ --------------
Net change in revolving lines of credit 25,702 (19,210) -- 6,492
Payments of long-term debt -- (15,453) (2,523) (17,976)
Distributions to minority interests -- (7,868) -- (7,868)
Dividends paid (15,632) -- -- (15,632)
Proceeds from stock options exercised 1,239 -- -- 1,239
Transactions with affiliates, net 12,115 4,904 (17,019) --
Other 1,262 -- -- 1,262
------------ ------------ ------------ --------------
Net cash provided by (used in) financing activities 24,686 (37,627) (19,542) (32,483)
------------ ------------ ------------ --------------
Effect of exchange rate changes on cash and equivalents -- -- 22 22
Net increase (decrease) in cash and cash equivalents (24,734) (2,837) 4,829 (22,742)
Cash and cash equivalents at beginning of period 28,121 6,501 4,000 38,622
------------ ------------ ------------ --------------
Cash and cash equivalents at end of period $ 3,387 $ 3,664 $ 8,829 $ 15,880
============ ============ ============ ==============
23
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
CAUTIONARY NOTICE REGARDING FORWARD-LOOKING STATEMENTS
This quarterly report includes statements of our expectations, intentions,
plans and beliefs that constitute "forward-looking statements" within the
meaning of Section 27A of the Securities Act of 1933 and Section 21E of the
Securities Exchange Act of 1934 and are intended to come within the safe harbor
protection provided by those sections. These statements relate to future events
or our future financial performance. We use words such as "anticipate,"
"believe," "expect," "may," "project," "will" or other similar words to identify
forward-looking statements.
Without limiting the foregoing, all statements relating to our future
outlook, anticipated capital expenditures, future cash flows and borrowings, and
sources of funding are forward-looking statements. These forward-looking
statements are based on numerous assumptions that we believe are reasonable, but
they are open to a wide range of uncertainties and business risks and actual
results may differ materially from those discussed in these statements.
Among the factors that could cause actual results to differ materially are:
- growth in coal and power markets;
- coal's market share of electricity generation;
- the extent of the economic recovery and future economic conditions;
- milder than normal weather;
- railroad and other transportation performance and costs;
- the ability to renew sales contracts upon expiration or renegotiation;
- the ability to successfully implement operating strategies;
- the effectiveness of our cost-cutting measures;
- regulatory and court decisions;
- future legislation;
- changes in postretirement benefit and pension obligations;
- credit, market and performance risk associated with our customers;
- modification or termination of our long-term coal supply agreements;
- reductions of purchases by major customers;
- risks inherent to mining, including geologic conditions or unforeseen
equipment problems;
- terrorist attacks or threats affecting our or our customers'
operations;
- changes in interpretation of tax law, including changes in Internal
Revenue Service interpretations related to synfuel activities;
- replacement of reserves;
24
- implementation of new accounting standards;
- inflationary trends and interest rate changes;
- the effects of interest rate changes on discounting future liabilities;
- the effects of acquisitions or divestitures; and
- other factors, including those discussed in "Legal Proceedings."
When considering these forward-looking statements, you should keep in mind
the cautionary statements in this document, the "Risks Relating to Our Company"
section of Item 7 of our 2002 Annual Report on Form 10-K filed with the
Securities and Exchange Commission and all documents incorporated by reference
in this quarterly report. We will not update these statements unless the
securities laws require us to do so.
QUARTER ENDED SEPTEMBER 30, 2003 COMPARED TO QUARTER ENDED SEPTEMBER 30, 2002
Sales. Sales for the quarter ended September 30, 2003 of $682.0 million
were $6.9 million below the corresponding prior year quarter. The prior year
quarter included $27.7 million in revenue related to a favorable arbitration
ruling that resulted in a retroactive price adjustment to our Navajo station
coal supply agreement. Excluding the revenue related to the arbitration ruling,
sales increased $20.8 million due to higher volume and pricing at our Powder
River Basin operations and higher brokerage sales volume.
Mining and brokerage operations' sales volume totaled 49.3 million tons for
the current year quarter, a 6.9% increase over the prior year level of 46.1
million tons. The increase was due to higher demand-driven volume at our Powder
River Basin operations and higher volume from our brokerage operations. Our
average sales price decreased 7.5% from the prior year quarter, primarily due to
the effect of the arbitration ruling in the prior year quarter and changes in
sales mix. Shipments from the Appalachia and Midwest regions represented a lower
percentage of overall sales in the current year, due to the increase in Powder
River Basin sales volume in the current year. Average prices in our brokerage
operations also decreased in the current year, as more Powder River Basin
products were shipped in the current year. Excluding the effect of the
arbitration ruling in the prior year, our average sales price decreased 3.6%.
U.S. Mining operations' sales were $4.5 million above the prior year
quarter, after excluding the effect of the arbitration ruling on prior year
sales. In the west, sales in the Powder River Basin operations increased $15.2
million on improved pricing and volume in the third quarter. Strong demand was
reflected in higher prices and record shipments of 28.3 million tons in the
quarter. Sales in the Southwest region decreased $30.7 million; however, sales
were comparable to the prior year after excluding $27.7 million in sales related
to the arbitration ruling in the prior year quarter.
Sales in the Appalachian region were $4.6 million lower than the prior year
quarter, as lower production at the Harris and certain contract mines resulted
from a tear in a conveyor belt. The Midwest region's sales were $3.1 million
less than the prior year quarter due to longer than expected ramp-up of
production due to equipment problems at the Highland Mine, and the ramp-up of
production at the Vermilion Grove portal of the Riola Mine.
Sales from brokerage operations increased $10.0 million over the prior year
quarter due to higher U.S. brokerage sales and Australian brokerage export
sales. Sales from our Australian Mining operations, which were acquired in the
third quarter of 2002, increased $6.3 million from the prior year quarter.
Other Revenues. Other revenues decreased $5.7 million from the prior year
quarter. The prior year quarter included a $15.1 million gain related to a
mediated settlement regarding the Mohave Generating Station coal supply
agreement. Excluding the $15.1 million gain in the prior year quarter, other
revenues increased $9.4 million, due to higher mark-to-market revenues from
trading operations, coal royalties and coalbed methane revenues.
25
Asset Retirement Obligation Expense. We recognized asset retirement
obligation expense of $7.5 million during the current year quarter, comprised of
the accretion of the asset retirement obligation liability and the amortization
of the asset retirement obligation asset recognized in accordance with SFAS No.
143. Expense in the prior year related to reclamation activities was $4.1
million and was included in "operating costs and expenses" in the statement of
operations for the quarter ended September 30, 2002. The adoption of SFAS No.
143 is discussed in Note 3 to the unaudited condensed consolidated financial
statements included in this report.
Selling and Administrative Expenses. Selling and administrative expenses
decreased $2.5 million due to lower headcount in 2003 and expenses related to
incentive plans based on our common stock price.
Net Gain on Property and Equipment Disposals. Net gain on property and
equipment disposals related to our resource management business increased $3.6
million due to a $1.4 million gain on the sale of surplus surface land in the
Midwest, combined with other miscellaneous asset sales.
Operating Profit. Operating profit decreased $15.7 million to $35.6 million
for the quarter ended September 30, 2003. The prior year quarter includes $37.1
million of profit related to the arbitration ruling and mediation settlement
described above. Excluding these two items, operating profit increased $21.4
million. Operating profit related to U.S. Mining operations (which excludes
operating costs related to past mining activities and net gains on property
disposals) increased $14.6 million, excluding the $37.1 million of profit in the
prior year related to the arbitration ruling and mediation settlement. The
increase was driven by improved margins in the Powder River Basin and Southwest
regions. Overall, our U.S. Mining operations held the line on costs compared
with the prior year, despite higher healthcare, pension, fuel and explosives
costs.
The Powder River Basin region's operating profit increased $10.6 million
from improved prices and volume and lower repair and maintenance expense. The
Southwest region's operating profit, excluding the $37.1 million of profit
related to the arbitration ruling and mediation settlement in the prior year
quarter, increased $9.5 million, primarily due to lower repair and maintenance
expenses.
In the east, the Appalachia region's operating profit approximated prior
year results as improved results at the Federal and Big Mountain mines helped
offset the effects of lower production at the Harris and contract mines from a
tear in a conveyor belt. Operating profit in the Midwest region decreased $4.6
million compared to the prior year quarter. Production was lower than expected
at the new Highland Mine due to equipment performance problems.
Operating profit from Trading and Brokerage operations increased $4.2
million. Trading profits were comparable with the prior year, while current year
brokerage results were favorably impacted by adopting EITF Issue 02-3
"Accounting for Contracts Involved in Energy Trading and Risk Management
Activities." Current quarter Trading and Brokerage results included $2.5 million
in unrealized profit related to a contract restructuring wherein a derivative
contract was modified to include tonnage from a non-derivative contract, which
increased the mark-to-market profit required to be recognized on the derivative
contract. The unrealized profit related to this contract will be converted to
cash by the end of 2004.
Operating profit for the current year period was also affected by higher
net gains on property and equipment disposals of $3.6 million and lower selling
and administrative expenses of $2.5 million discussed above, offset by asset
retirement obligation expense of $7.5 million. Finally, operating costs related
to past mining activities were comparable with the prior year quarter, as higher
reclamation expense at closed mine locations in the prior year was offset by
higher retiree healthcare costs in the current year.
Interest Expense. Interest expense decreased $3.5 million from the prior
year quarter, to $22.3 million. Lower borrowing costs of $4.9 million resulted
from the refinancing of our debt (see complete discussion in Note 2 to the
unaudited condensed consolidated financial statements). Lower borrowing costs
26
were partially offset by $1.4 million in higher costs in the current quarter
related to surety bonds and letters of credit used to secure our obligations for
reclamation, workers' compensation and lease commitments.
Income Taxes. For the quarter ended September 30, 2003, we recorded an
income tax benefit of $8.6 million on income before income taxes and minority
interests of $13.6 million, compared to an income tax benefit of $1.5 million on
income before income taxes and minority interests of $31.0 million in the prior
year quarter. The tax benefit recorded in the third quarter of 2003 as a
percentage of income before income taxes and minority interests is greater than
the tax benefit recorded in the same quarter for the prior year primarily as a
result of the magnitude of the percentage depletion deduction (which is a
permanent difference) relative to pre-tax income. The income tax benefit for the
current year quarter results primarily from the magnitude of the percentage
depletion deduction.
Minority Interests. For the quarter ended September 30, 2003, minority
interests expense decreased $2.8 million to $0.7 million. The reduction was due
to the purchase of the remaining 25% of Arclar Coal Company in September 2002
and the acquisition in April 2003 of the remaining 18.3% of Black Beauty Coal
Company. The minority interest expense that continues to be recorded subsequent
to April 2003 relates to a 75%-owned subsidiary of Black Beauty Coal Company.
NINE MONTHS ENDED SEPTEMBER 30, 2003 COMPARED TO NINE MONTHS ENDED SEPTEMBER 30,
2002
Sales. Sales for the nine months ended September 30, 2003 of $2,010.8
million were $43.3 million, or 2.2%, above the corresponding prior year period,
as higher pricing and volume in the Powder River Basin, higher brokerage volume
and higher Australian export volume overcame lower production at our Appalachia
operations related to weather-related production disruptions and at our Midwest
operations related to customer repairs and lower than expected production at the
Highland Mine, the Vermilion Grove portal of the Riola Mine and the Willow Lake
Mine. The prior year period included $27.7 million in sales related to the
favorable arbitration ruling discussed above.
Mining and brokerage operations' sales volume totaled 143.5 million tons
for the current year period, a 4.7% increase over the prior year level of 137.0
million tons. Higher volume from our brokerage and Australian Mining operations
more than offset slightly lower volume at our U.S. Mining operations. Our
average sales price decreased 2.5% over the prior year period, due mainly to the
effect of the favorable arbitration ruling in the prior year and sales mix, as
higher priced tons in the Appalachia and Midwest regions represented a lower
percentage of overall sales in the current year compared to the prior year
period. Additionally, average prices in our brokerage operations decreased, as
our volume was more heavily weighted toward western coal shipments in the
current year.
U.S. Mining operations' sales were $71.3 million below the prior year
period, primarily as a result of the prior year arbitration ruling and lower
volume in Appalachia and the Midwest, which more than offset higher prices and
volume in the Powder River Basin. Sales in the Appalachian region were $55.1
million lower than the prior year period, as production was reduced by mine
disruptions caused by weather in both the first quarter and second quarter,
along with the installation of new longwall equipment and development of a new
reserve area at the Federal Mine. Midwest sales decreased $11.9 million, as the
new Highland mine's production has not yet reached levels comparable with
production in the prior year period at the predecessor Camp No. 11 mine, which
ceased operations during the fourth quarter of 2002. In addition, customer
repairs lowered volume in the first half of 2003.
Sales in the Powder River Basin increased $33.2 million as improved pricing
for the current year period and record volume in the second and third quarters
more than offset lower volume in the first quarter as a result of heavy
snowfall. Sales in the Southwest region decreased $37.5 million as a result of
the prior year arbitration ruling ($27.7 million) and lower volume in the
current year due to two customers performing major repairs in the first half of
the year.
Sales from brokerage operations increased $95.5 million over the prior year
period due to higher U.S. brokerage sales and Australian brokerage export sales.
Our Australian Mining operations, which were acquired in the third quarter of
2002, contributed higher year-over-year sales of $19.2 million.
27
Other Revenues. Other revenues decreased $14.1 million from the prior year
period due to the $15.1 million gain related to the mediated settlement
discussed above. In addition, slightly higher trading and coalbed methane
revenues were offset by lower revenues related to a royalty agreement that
expired in 2002.
Asset Retirement Obligation Expense. We recognized asset retirement
obligation expense of $20.6 million during the current year, comprised of the
accretion of the asset retirement obligation liability and the amortization of
the asset retirement obligation asset recognized in accordance with SFAS No.
143. Expense in the prior year related to reclamation activities was $12.8
million and was included in "operating costs and expenses" in the statement of
operations for the nine months ended September 30, 2002. The adoption of SFAS
No. 143 is discussed in Note 3 to the unaudited condensed consolidated financial
statements included in this report.
Selling and Administrative Expenses. Selling and administrative expenses
increased $4.2 million due to higher costs associated with salaried pensions,
incentive compensation, litigation, additional healthcare cost controls and
Sarbanes-Oxley compliance. Lower headcount in 2003 helped offset some of these
cost increases.
Net Gain on Property and Equipment Disposals. Net gain on property and
equipment disposals related to our resource management business increased $19.9
million primarily due to a sale of land and coal reserves in Appalachia in the
second quarter of 2003 and the sale of oil and gas rights in Appalachia in the
first quarter of 2003, combined with the net gain on property and equipment
disposals discussed above.
Operating Profit. Operating profit decreased $61.1 million to $100.4
million for the nine months ended September 30, 2003. The prior year period
includes $37.1 million of profit related to the arbitration ruling and mediation
settlement described above. Operating profit from U.S. Mining operations (which
excludes operating costs related to past mining activities and net gains on
property disposals) decreased $50.9 million, which includes the $37.1 million
benefit from the arbitration ruling and mediation settlement in the prior year.
In addition, the current year was impacted by operating below optimal levels as
a result of customer repairs and weather disruptions in the first half of the
year, higher reclamation costs related to the adoption of SFAS No. 143, and
higher pension and retiree healthcare costs.
In the west, the Powder River Basin region's operating profit increased
$23.9 million on improved prices, record volume in the second and third quarter,
and lower maintenance and repair costs, which overcame higher fuel and
explosives costs. The Southwest region's operating profit, excluding the $37.1
million of profit related to the arbitration ruling and mediation settlement in
the prior-year period, increased $5.0 million, as lower maintenance and repair
expense more than offset lower volume from outages at two customer plants in the
first half of the current year period.
In the east, the Appalachia region's operating profit decreased $28.7
million due to lower volume from geologic difficulties and weather disruptions
at the Harris Mine, lower shipments from contract mines and the conveyor belt
tear previously mentioned. Operating profit in the Midwest region decreased
$14.0 million compared to the prior year period due to higher fuel and
explosives costs at our Black Beauty operations and lower volume due to customer
repairs and ramp-up issues at the new Highland Mine and the Vermilion Grove
portal of the Riola Mine, which have not reached full production capacity.
Operating profit from Trading and Brokerage operations increased $6.9
million over the prior year, primarily due to higher profit from improved
brokerage volume and the impact of adopting EITF Issue 02-3 "Accounting for
Contracts Involved in Energy Trading and Risk Management Activities." Current
year Trading and Brokerage results included $6.8 million in unrealized profit
related to a contract restructuring wherein the new contract's terms and
conditions required it to be classified as a derivative and marked to market for
accounting purposes. The unrealized profit related to this contract will be
converted to cash by the end of 2005. An additional $4.1 million of unrealized
profit related to two other contract modifications, including the modification
described above in the analysis of results for the quarter ended September 30,
2003. The unrealized profit related to these two contract modifications will be
converted to cash by the end of 2004.
28
Operating profit for the current year period was also affected by higher
net gains on property and equipment disposals of $19.9 million offset by asset
retirement obligation expense of $20.6 million and higher selling and
administrative expenses of $4.2 million.
Operating costs related to past mining activities were $10.9 million higher
in the current year period, due to $7.8 million of higher retiree healthcare
costs in the current year, driven by lower interest discount rate and higher
inflation trend assumptions, combined with $7.0 million in excise tax refunds
included in the prior year. Finally, prior year resource management results
included royalty income of $4.0 million related to a royalty agreement that
expired in 2002.
Interest Expense. Interest expense increased $0.6 million compared to the
prior year period, to $77.4 million. Interest savings from the March 2003
refinancing were not fully realized until the third quarter (discussed above)
because the second quarter included $5.3 million in interest costs for the notes
not redeemed until May 15, 2003. In addition, we incurred $5.3 million in higher
costs in the nine months ended September 30, 2003 related to surety bonds and
letters of credit used to secure our obligations for reclamation, workers'
compensation and lease commitments. These additional expenses were partially
offset by lower interest on $650 million of 6.875% Senior Notes issued in March
2003 and lower overall interest costs of $4.9 million in the third quarter,
discussed above.
Early Debt Extinguishment Costs. Pursuant to our debt refinancing
transactions discussed in Note 2 to the unaudited condensed consolidated
financial statements, we incurred early debt extinguishment costs of $53.5
million during the nine months ended September 30, 2003, which were comprised of
$41.8 million of early prepayment premiums and fees paid to retire debt, $17.5
million of debt issuance costs that were written off in conjunction with the
early extinguishment of debt, partially offset by a gain on the termination of
related interest rate swaps of approximately $5.8 million.
Income Taxes. For the nine months ended September 30, 2003, there was an
income tax benefit of $49.6 million on a loss before income taxes and minority
interests of $27.9 million, compared to income tax expense of $4.6 million on
income before income taxes and minority interests of $91.4 million in the prior
year period. The tax benefit recorded in the first nine months of 2003 differs
from the tax expense in the prior year nine-month period primarily as a result
of the magnitude of the percentage depletion deduction (which is a permanent
difference) relative to pre-tax income. The income tax benefit for the current
year period results primarily from the magnitude of the percentage depletion
deduction and a $10.0 million adjustment to our tax reserves.
Minority Interests. For the nine months ended September 30, 2003, minority
interests expense decreased $8.5 million to $2.4 million. The reduction was due
to the minority interest acquisitions discussed above and the impact of $7.3
million of early debt extinguishment charges incurred at Black Beauty during
2003.
Cumulative Effect of Accounting Changes, Net of Taxes. As of January 1,
2003, we recognized expense relating to the cumulative effect of accounting
changes, net of income taxes, of $10.1 million. This amount represents the
aggregate amount of the recognition of accounting changes pursuant to the
adoption of SFAS No. 143, the change in method of amortization of actuarial
gains and losses related to net periodic postretirement benefit costs and the
effect of the rescission of EITF No. 98-10, as discussed in Note 3 to the
unaudited condensed consolidated financial statements.
29
LIQUIDITY AND CAPITAL RESOURCES
Cash provided by operating activities was $115.8 million for the nine
months ended September 30, 2003, a decrease of $92.8 million from the
corresponding prior year period. The decrease is primarily due to lower income
from continuing operations in the current year, and the prior year period's cash
flows include $26.8 million of excise tax refunds and $22.1 million received
related to the arbitration ruling previously mentioned.
Net cash used in investing activities was $183.2 million for the nine
months ended September 30, 2003, $15.7 million lower than the corresponding
prior year period. Capital expenditures decreased $42.5 million, to $118.8
million, in the current year period. Major expenditures incurred in the nine
months ended September 30, 2003 related to the startup of the Highland Mine and
the installation of new longwall equipment and development of a new reserve area
at our 5 million ton per year Federal Mine. Other capital expenditures were
primarily for the replacement of mining equipment, the expansion of capacity at
certain mines and projects to improve the efficiency of mining operations.
Acquisition expenditures increased $44.5 million in the current year, due to the
current year $90.0 million acquisition of the remaining 18.3% of Black Beauty
Coal Company, discussed in Note 4 to the unaudited condensed consolidated
financial statements. The prior year included $44.5 million of expenditures
related to the acquisitions of Beaver Dam Coal Company, remaining 25% interest
in Arclar Coal Company and our Australian Mining operations. Finally, the
current year period included $18.2 million higher proceeds from property and
equipment disposals as a result of sales of land, coal reserves and oil and gas
rights during the period.
Net cash provided by financing activities was $101.1 million for the nine
months ended September 30, 2003, a $133.6 million increase over the
corresponding prior year period. The current year included proceeds from
long-term debt of $1.1 billion from the refinancing transactions. A detailed
discussion of the sources and uses of proceeds from the refinancing transactions
is included in Note 2 to the unaudited condensed consolidated financial
statements. The refinancing proceeds were used, among other things, to repay
line of credit borrowings of $121.6 million, long-term debt of $831.0 million
and to pay $23.6 million in debt issuance costs in connection with the new debt
issued. The current year includes other debt repayments of $35.1 million, while
the prior year includes net repayments of $11.5 million. Financing cash flows in
the current and prior year periods reflect dividends paid of $17.3 million and
$15.6 million, respectively. Finally, the current year period included $24.6
million of proceeds from the exercise of stock options.
As of September 30, 2003 and December 31, 2002, our total indebtedness
consisted of the following (dollars in thousands):
September 30, 2003 December 31, 2002
------------------ -----------------
Term Loan under Senior Secured Credit Facility $ 447,750 $ --
6.875% Senior Notes due 2013 650,000 --
Fair value of interest rate swaps - 6.875% Senior Notes 7,285 --
9.625% Senior Subordinated Notes redeemed in 2003 -- 391,490
8.875% Senior Notes redeemed in 2003 -- 316,498
5.0% Subordinated Note 78,273 85,055
Senior unsecured notes under various agreements -- 58,214
Unsecured revolving credit agreement -- 116,584
Other 17,389 61,370
------------------ -----------------
$ 1,200,697 $ 1,029,211
================== =================
During the nine months ended September 30, 2003, we completed a
comprehensive debt refinancing to lower our borrowing costs, expand our
borrowing capacity, extend our debt maturities and simplify our capital
structure. Our Senior Secured Credit Facility and 6.875% Senior Notes have been
rated Ba1 and BB-, respectively, by Moody's Investors Service, BB+ and BB- by
Standard & Poor's and BB+ and BB by Fitch. Recently, Moody's reaffirmed our
SGL-1 liquidity rating. Under Moody's rating system, SGL-1 means "very
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good" liquidity. Moody's SGL ratings are used to supplement their credit ratings
for companies rated from "Ba1" to "C."
These security ratings reflect the views of the rating agencies only. An
explanation of the significance of these ratings may be obtained from each
rating agency. Such ratings are not a recommendation to buy, sell or hold
securities, but rather an indication of creditworthiness. Any rating can be
revised upward or downward or withdrawn at any time by a rating agency if it
decides that the circumstances warrant the change. Each rating should be
evaluated independently of any other rating.
In July 2003, our board of directors approved a 25% increase in the regular
quarterly dividend on common stock, to $0.125 per share. The increased dividend
was paid on August 26, 2003, to shareholders of record on August 5, 2003.
In May 2003, we entered into and designated four interest rate swaps with
notional amounts totaling $100.0 million as a fair value hedge of our 6.875%
Senior Notes. Under the swaps, the Company pays a floating rate that resets each
March 15 and September 15, based upon the six-month LIBOR rate, for a period of
ten years ending March 15, 2013 and receives a fixed rate of 6.875%. The
applicable floating rate was 4.25% as of September 30, 2003. At current LIBOR
levels, we would realize annualized savings of approximately $2.6 million over
the term of the swaps.
In September 2003, the Company entered into two $400.0 million interest
rate swaps. One $400.0 million notional amount floating-to-fixed interest rate
swap, expiring March 15, 2010, was designated as a hedge of changes in expected
cash flows on the term loan under Senior Secured Credit Facility. Under this
swap, the Company pays a fixed rate of 6.764% and receives a floating rate of
LIBOR plus 2.5% that resets quarterly based upon the three-month LIBOR rate.
Another $400.0 million notional amount fixed-to-floating interest rate swap,
expiring March 15, 2013, was designated as a hedge of the changes in the fair
value of the 6.875% Senior Notes due 2013. Under this swap, the Company pays a
floating rate of LIBOR plus 1.97% that resets quarterly based upon the
three-month LIBOR rate and receives a fixed rate of 6.875%. The effect of the
swaps was to lower the Company's overall borrowing costs on $400.0 million of
debt principal by 0.64% as of September 30, 2003, which will result in
annualized interest savings of $2.6 million over the term of the
fixed-to-floating swap.
As of September 30, 2003, there were no outstanding borrowings under our
Revolving Credit Facility. We had letters of credit outstanding under the
facility of $241.0 million, leaving $359.0 million available for borrowing. We
were in compliance with all of the covenants of the Senior Secured Credit
Facility and 6.875% Senior Notes as of September 30, 2003.
We had $67.7 million of commitments for capital expenditures at September
30, 2003, that are primarily related to acquiring additional coal reserves and
mining equipment. The majority of these commitments relate to spending targeted
for 2003. Total projected capital expenditures for calendar year 2003 are
approximately $175 million to $190 million, and have been and will be primarily
used to develop existing reserves, replace or add equipment and fund cost
reduction initiatives. We anticipate funding our capital expenditures primarily
through operating cash flow.
Off-Balance Sheet Arrangements
In March 2000, we established an accounts receivable securitization
program. Under the program, undivided interests in a pool of eligible trade
receivables that have been contributed to our wholly-owned, bankruptcy-remote
subsidiary 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. We used proceeds from the sale of the
accounts receivable to repay long-term debt, effectively reducing our overall
borrowing costs. The securitization program is currently scheduled to expire in
2007, and the maximum amount of undivided interests in accounts receivable that
may be sold to the Conduit is $140.0 million. Under the provisions of SFAS No.
140 "Accounting for Transfers and Servicing of Financial Assets and
Extinguishments of Liabilities," 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
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undivided interests in accounts receivable sold to the Conduit was $140.0
million and $136.4 million as of September 30, 2003 and December 31, 2002,
respectively.
There were no other material changes to our off-balance sheet arrangements
during the nine months ended September 30, 2003. All off-balance sheet
arrangements are discussed in "Management's Discussion and Analysis of Financial
Condition and Results of Operations" in our Form 10-K for the year ended
December 31, 2002.
OTHER
Mohave Generating Station
See Note 10 to the unaudited condensed consolidated financial statements
included in this report relating to the potential cessation or suspension of the
operations of the Mohave Generating Station on December 31, 2005. The Mohave
Generating Station is the sole customer of our Black Mesa Mine, which sold 4.6
million tons of coal in 2002.
Big Sky Mine
Our Big Sky Mine, which is located in the northern Powder River Basin near
Colstrip, Montana, sold 2.8 million tons of medium sulfur coal during 2002. As
disclosed in our Form 10-K for the year ended December 31, 2002, the mine is
near the exhaustion of its economically recoverable reserves. The mine's current
sales contract expires on December 31, 2003, and we anticipate that we will
close the mine after that sales contract expires. The mine's closure will not
have a material adverse effect on our financial condition, results of operations
or cash flows.
Gibraltar P&L Mine
Our Gibraltar P&L Mine, which is a small surface pit located near our
former Gibraltar Mine near Graham, Kentucky, will close in the fourth quarter of
2003 as it exhausts its economically recoverable reserves. The mine sold 0.8
million tons of coal during 2002. The Gibraltar P&L Mine closure will not have a
material adverse effect on our financial condition, results of operations or
cash flows.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
Trading Activities
Our coal trading activities give rise to commodity price 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 adjust traded
position levels to remain within risk limits prescribed by management. 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 trading derivatives under SFAS No. 133 (as amended),
which requires us to reflect derivatives, such as forwards, futures, options and
swaps, at market value in the consolidated financial statements.
We perform a value at risk analysis on our trading portfolio, which
includes over-the-counter and brokerage trading of coal. The use of value at
risk allows us to quantify in dollars, on a daily basis, the price risk inherent
in our trading portfolio. Our value at risk model is based on the industry
standard risk-metrics variance/co-variance approach. This captures our exposure
related to both option and forward positions. Our value at risk model assumes a
15-day holding period and a 95% one-tailed confidence interval.
The use of value at risk allows management to aggregate pricing risks
across products in the portfolio, compare risk on a consistent basis and
identify the drivers of risk. Due to the subjectivity in the choice of the
liquidation period, reliance on historical data to calibrate the models and the
inherent limitations in the value at risk methodology, including the use of
delta/gamma adjustments related to options, we perform regular
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stress, back testing and scenario analysis to estimate the impacts of market
changes on the value of the portfolio. The results of these analyses are used to
supplement the value at risk methodology and identify additional market-related
risks.
During the nine months ended September 30, 2003, the low, high and average
values at risk for our coal trading portfolio were $0.4 million, $1.3 million
and $0.8 million, respectively. As of September 30, 2003, 13% of the value of
our trading portfolio was scheduled to be realized by the end of calendar year
2003, and 97% of the value of our trading portfolio was scheduled to be realized
by the end of calendar year 2004.
We also monitor other types of risk associated with our coal trading
activities, including credit, market liquidity and counterparty nonperformance.
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. As of September 30, 2003, we had sales commitments for
substantially all of our planned calendar 2003 production. We have committed and
priced 168 million tons of planned 2004 production of 190 million to 200 million
tons.
Some of the products used in our mining activities, such as diesel fuel and
explosives, are subject to price volatility. We, through our suppliers, utilize
forward contracts to manage the exposure related to this volatility.
We have exposure to changes in interest rates due to our existing level of
indebtedness. As of September 30, 2003, after taking into consideration the
effects of interest rate swaps, we had $647.4 million of fixed-rate borrowings
and $553.3 million of variable-rate borrowings outstanding. A one percentage
point increase in interest rates would result in an annualized increase to
interest expense of $5.5 million on our variable-rate borrowings. With respect
to our fixed-rate borrowings, a one-percentage point increase in interest rates
would result in a $49.7 million decrease in the fair value of these borrowings.
ITEM 4. CONTROLS AND PROCEDURES.
The Chief Executive Officer and Executive Vice President and Chief
Financial Officer have evaluated our disclosure controls and procedures as of
September 30, 2003 and have concluded that the disclosure controls and
procedures were effective. Our disclosure controls and procedures are designed
to, among other things, provide reasonable assurance that material information,
both financial and non-financial, and other information required under the
securities laws to be disclosed is identified and communicated to senior
management on a timely basis.
Additionally, during the most recent fiscal quarter, there have been no
changes to our internal control over financial reporting that could materially
affect, or are reasonably likely to materially affect, our internal control over
financial reporting.
PART II -- OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS.
Navajo Nation
See Note 10 to the unaudited condensed consolidated financial statements
included in Part I, Item 1 of this report relating to certain legal proceedings
brought against us by the Navajo Nation and Hopi Tribe.
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Oklahoma Lead Litigation
One of our subsidiaries, Gold Fields, was named in June 2003 as a
defendant, along with five other companies, in a class action lawsuit filed in
the U.S. District Court for the Northern District of Oklahoma. The plaintiffs
have asserted nuisance and trespass claims predicated on allegations of
intentional lead exposure by the defendants, including Gold Fields, and are
seeking compensatory damages for diminution of property value, punitive damages
and the implementation of medical monitoring and relocation programs for the
affected individuals. A predecessor of Gold Fields formerly operated two lead
mills near Picher, Oklahoma prior to the 1950's. The plaintiff classes include
all persons who have lived in the vicinity of Picher within a specified time
period. Gold Fields has agreed to indemnify one of the other defendants, which
is a former subsidiary of our company. Gold Fields is also a defendant, along
with other companies, in 17 individual lawsuits arising out of the same lead
mill operations involved in the class action. Plaintiffs in these actions are
seeking compensatory and punitive damages for alleged personal injuries from
lead exposure. Four of those lawsuits have been consolidated for a trial set for
November 17, 2003 in the U.S. District Court for the Northern District of
Oklahoma.
While the outcome of litigation is subject to uncertainties, based on the
Company's preliminary evaluation of the issues and their potential impact on the
Company, the Company believes this matter will be resolved without a material
adverse effect on the Company's financial condition, results of operations or
cash flows.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K.
(a) Exhibits
See Exhibit Index at page 36 of this report.
(b) Reports on Form 8-K
On July 17, 2003, we furnished a Form 8-K under Item 9, Regulation FD
Disclosure and Item 12, Disclosure of Results of Operations and Financial
Condition announcing our issuance of a press release setting forth our
second quarter 2003 earnings, and providing guidance on our third quarter
and full year 2003 forecasted results. The press release was included as an
exhibit under Item 7, Financial Statements, Pro Forma Financial Information
and Exhibits.
On August 4, 2003, we filed a Form 8-K under Item 5, Other Events and
Regulation FD Disclosure, announcing an underwriting agreement between the
Company, certain stockholders and certain named underwriters, pursuant to
the secondary offering as discussed in Note 12 to the unaudited condensed
consolidated financial statements. The underwriting agreement was included
as an exhibit under Item 7, Financial Statements, Pro Forma Financial
Information and Exhibits.
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SIGNATURE
Pursuant to the requirements 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
Date: November 13, 2003 By: /s/ RICHARD A. NAVARRE
------------------------------------
Richard A. Navarre
Executive Vice President and Chief
Financial Officer
(Principal Financial Officer)
35
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
Company'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 to the Company's Quarterly Report
on Form 10-Q for the quarter ended September 30, 2002 filed on
November 14, 2002).
4.29 Second Supplemental Senior Note Indenture dated as of
September 30, 2003 among Peabody Energy Corporation, the
Guaranteeing Subsidiaries (as defined therein) and US Bank
National Association, as trustee (incorporated by reference to
the Exhibit 4.198 of the Company's Form S-3 Registration
Statement on No. 333-109906, filed on October 22, 2003).
10.47* Agreement between Peabody Energy Corporation and Richard A.
Navarre dated August 29, 2003.
10.48* Agreement between Peabody Energy Corporation and Richard M.
Whiting dated September 24, 2003.
31.1* Certification of periodic financial report by Peabody Energy
Corporation's Chief Executive Officer pursuant to Rule
13a-14(a) under the Securities Exchange Act of 1934, as
amended pursuant to Section 302 of the Sarbanes-Oxley Act of
2002.
31.2* Certification of periodic financial report by Peabody Energy
Corporation's Executive Vice President and Chief Financial
Officer pursuant to Rule 13a-14(a) under the Securities
Exchange Act of 1934, as amended pursuant to Section 302 of
the Sarbanes-Oxley Act of 2002.
32.1* Certification of periodic financial report pursuant to 18
U.S.C. Section 1350, adopted pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002, by Peabody Energy Corporation's
Chief Executive Officer.
32.2* Certification of periodic financial report pursuant to 18
U.S.C. Section 1350, adopted pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002, by Peabody Energy Corporation's
Executive Vice President and Chief Financial Officer.
* Filed herewith.
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