<PAGE> 1
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
/x/ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 1996
OR
/ / TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
Commission file number: 1-13298
ZEIGLER COAL HOLDING COMPANY
(Exact name of registrant as specified in its charter)
DELAWARE 36-3344449
(State of incorporation) (I.R.S. Employer Identification No.)
<TABLE>
<S><C>
50 JEROME LANE
FAIRVIEW HEIGHTS, ILLINOIS 62208 (618) 394-2400
(Address of principal executive offices) (Zip Code) (Registrant's telephone number,
including area code)
</TABLE>
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 report(s), and (2) has been subject to
such filing requirements for the past 90 days. [x] Yes [ ] No
As of November 7, 1996, a total of 28,367,946 shares of the Registrant's common
stock were outstanding.
<PAGE> 2
ZEIGLER COAL HOLDING COMPANY
FORM 10-Q
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 1996
TABLE OF CONTENTS
<TABLE>
<CAPTION>
ITEM PAGE
- ---- ----
PART I
<S> <C> <C>
1 FINANCIAL STATEMENTS:
Condensed Consolidated Statements of Operations - Three and Nine
Months Ended September 30, 1996 and 1995 . . . . . . . . . . . . . . 2
Condensed Consolidated Balance Sheets - September 30, 1996,
December 31, 1995 and September 30, 1995 . . . . . . . . . . . . . . 3
Condensed Consolidated Statements of Cash Flows - Nine Months
Ended September 30, 1996 and 1995 . . . . . . . . . . . . . . . . . . 5
Notes to Condensed Consolidated Financial Statements . . . . . . . . . . . 6
2 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
PART II
1 LEGAL PROCEEDINGS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
5 OTHER INFORMATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14
6 EXHIBITS AND REPORTS ON FORM 8-K . . . . . . . . . . . . . . . . . . . . . . . . 15
SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16
</TABLE>
<PAGE> 3
PART 1 - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
(See following pages.)
1
<PAGE> 4
ZEIGLER COAL HOLDING COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Amounts in thousands, except per share amounts)
<TABLE>
<CAPTION>
Quarter Ended Nine Months Ended
September 30, September 30,
------------- -------------
1996 1995 1996 1995
---- ---- ---- ----
(Unaudited) (Unaudited) (Unaudited) (Unaudited)
<S> <C> <C> <C> <C>
REVENUES:
Coal sales . . . . . . . . . . . . . . . . . . . . . . . $186,662 $191,248 $533,705 $570,641
Other revenues . . . . . . . . . . . . . . . . . . . . . . 6,560 6,840 23,236 20,813
-------- -------- -------- --------
Total revenues . . . . . . . . . . . . . . . . . . . 193,222 198,088 556,941 591,454
-------- -------- -------- --------
COSTS AND EXPENSES:
Cost of coal sales . . . . . . . . . . . . . . . . . . . . 167,928 178,431 462,487 510,282
Costs at inactive properties . . . . . . . . . . . . . . . (11,526) 3,965 (2,073) 9,758
Selling, general and administrative expenses . . . . . . . 4,905 4,238 13,764 12,403
Revaluation of stock appreciation units . . . . . . . . . 455 (188) 1,782 231
Reduction in accrued pneumoconiosis benefits . . . . . . . - (15,000) - (15,000)
Provision for asset impairments and accelerated
mine closings . . . . . . . . . . . . . . . . . . . . - - - 32,262
Other costs and expenses . . . . . . . . . . . . . . . . . 5,495 4,198 15,892 13,982
-------- -------- -------- --------
Total costs and expenses . . . . . . . . . . . . . . 167,257 175,644 491,852 563,918
-------- -------- -------- --------
OTHER INCOME:
Proceeds from contract settlement . . . . . . . . . . . . - - - 45,500
-------- -------- -------- --------
INCOME BEFORE INTEREST AND INCOME TAXES . . . . . . . . . . 25,965 22,444 65,089 73,036
INTEREST INCOME (EXPENSE):
Interest on borrowings . . . . . . . . . . . . . . . . . . (5,708) (6,325) (17,186) (20,999)
Amortization of deferred financing costs . . . . . . . . . (210) (207) (628) (630)
Interest income . . . . . . . . . . . . . . . . . . . . . 424 143 668 354
-------- -------- -------- --------
Net interest expense . . . . . . . . . . . . . . . . (5,494) (6,389) (17,146) (21,275)
-------- -------- -------- --------
INCOME BEFORE INCOME TAXES . . . . . . . . . . . . . . . . . 20,471 16,055 47,943 51,761
INCOME TAXES . . . . . . . . . . . . . . . . . . . . . . . . 3,480 3,693 8,165 12,170
-------- -------- -------- --------
NET INCOME . . . . . . . . . . . . . . . . . . . . . . . . . $ 16,991 $ 12,362 $ 39,778 $ 39,591
======== ======== ======== ========
Weighted average shares outstanding . . . . . . . . . . . . . 28,361 28,356 28,359 28,356
Net income per common share . . . . . . . . . . . . . . . . . $ 0.60 $ 0.44 $ 1.40 $ 1.40
</TABLE>
See notes to condensed consolidated financial statements.
2
<PAGE> 5
ZEIGLER COAL HOLDING COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Amounts in thousands, except per share amounts)
<TABLE>
<CAPTION>
September 30, December 31, September 30,
1996 1995 1995
---- ---- ----
(Unaudited) * (Unaudited)
ASSETS
------
<S> <C> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents . . . . . . . . . . . . . . . . . . . $ 88,704 $ 13,119 $ 22,339
Receivables:
Trade accounts receivable (net of allowances of $2,583,
$2,611 and $2,905) . . . . . . . . . . . . . . . . . . . . 57,237 67,175 65,791
Other receivables . . . . . . . . . . . . . . . . . . . . . . 4,990 4,912 4,710
---------- ---------- ----------
Total receivables, net . . . . . . . . . . . . . . . . . . 62,227 72,087 70,501
---------- ---------- ----------
Inventories:
Coal finished goods . . . . . . . . . . . . . . . . . . . . . 11,181 20,050 24,202
Coal work in process . . . . . . . . . . . . . . . . . . . . . 9,515 7,343 9,092
Mine supplies . . . . . . . . . . . . . . . . . . . . . . . . 21,017 22,966 29,104
---------- ---------- ----------
Total inventories . . . . . . . . . . . . . . . . . . . . . 41,713 50,359 62,398
---------- ---------- ----------
Income taxes receivable . . . . . . . . . . . . . . . . . . . . 1,773 - -
Deferred income taxes . . . . . . . . . . . . . . . . . . . . . 4,712 8,357 16,756
Other current assets . . . . . . . . . . . . . . . . . . . . . . 5,533 3,426 5,177
---------- ---------- ----------
Total current assets . . . . . . . . . . . . . . . . . . . 204,662 147,348 177,171
---------- ---------- ----------
PROPERTY, PLANT AND EQUIPMENT:
Land and mineral rights . . . . . . . . . . . . . . . . . . . . 626,341 633,091 654,309
Prepaid royalties . . . . . . . . . . . . . . . . . . . . . . . . 21,959 21,303 23,214
Plant and equipment . . . . . . . . . . . . . . . . . . . . . . 488,305 506,976 540,776
---------- ---------- ----------
Total at cost . . . . . . . . . . . . . . . . . . . . . . . 1,136,605 1,161,370 1,218,299
Less - Accum. depreciation, depletion and amortization. . . . . . (313,179) (302,714) (297,954)
---------- ---------- ----------
Property, plant and equipment, net . . . . . . . . . . . . 823,426 858,656 920,345
---------- ---------- ----------
OTHER ASSETS:
Prepaid pension expense . . . . . . . . . . . . . . . . . . . . 6,687 9,555 10,263
Deferred financing costs, net . . . . . . . . . . . . . . . . . 2,044 2,674 2,884
Deferred income taxes . . . . . . . . . . . . . . . . . . . . . . - 2,242 -
Other long-term assets . . . . . . . . . . . . . . . . . . . . . 4,355 4,766 4,153
---------- ---------- ----------
Total other assets . . . . . . . . . . . . . . . . . . . . 13,086 19,237 17,300
---------- ---------- ----------
TOTAL ASSETS . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,041,174 $1,025,241 $1,114,816
========== ========== ==========
</TABLE>
* Condensed from audited financial statements.
See notes to condensed consolidated financial statements.
3
<PAGE> 6
ZEIGLER COAL HOLDING COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Amounts in thousands, except per share amounts)
<TABLE>
<CAPTION>
September 30, December 31, September 30,
1996 1995 1995
---- ---- ----
(Unaudited) * (Unaudited)
LIABILITIES AND SHAREHOLDERS' EQUITY
------------------------------------
CURRENT LIABILITIES:
<S> <C> <C> <C>
Accounts payable - trade . . . . . . . . . . . . . . . . . . . . $ 36,706 $ 44,434 $ 34,001
Dividends payable . . . . . . . . . . . . . . . . . . . . . . . 2,127 1,418 1,418
Income taxes payable . . . . . . . . . . . . . . . . . . . . . . - 2,271 1,586
Other taxes payable . . . . . . . . . . . . . . . . . . . . . . 24,051 24,291 24,856
Accrued payroll and related benefits . . . . . . . . . . . . . . 24,303 25,264 31,397
Deferred revenue . . . . . . . . . . . . . . . . . . . . . . . . 7,610 - 10,204
Other accrued expenses . . . . . . . . . . . . . . . . . . . . . 42,251 19,890 26,349
---------- ---------- ----------
Total current liabilities . . . . . . . . . . . . . . . . . 137,048 117,568 129,811
---------- ---------- ----------
LONG-TERM DEBT . . . . . . . . . . . . . . . . . . . . . . . . . . 344,770 344,770 357,770
ACCRUED POSTRETIREMENT BENEFIT OBLIGATIONS . . . . . . . . . . . . 245,088 255,839 250,821
ACCRUED PNEUMOCONIOSIS BENEFITS . . . . . . . . . . . . . . . . . 48,057 49,424 56,907
ACCRUED MINE CLOSING COSTS . . . . . . . . . . . . . . . . . . . . 77,175 105,676 95,964
DEFERRED INCOME TAXES . . . . . . . . . . . . . . . . . . . . . . 9,400 - 25,981
OTHER LONG-TERM LIABILITIES:
Accrued workers' compensation . . . . . . . . . . . . . . . . . 37,307 30,766 27,502
Accrued postemployment benefits . . . . . . . . . . . . . . . . 17,741 17,284 15,501
Stock appreciation units . . . . . . . . . . . . . . . . . . . . 4,132 15,075 12,200
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4,086 7,353 8,651
---------- ---------- ----------
Total other long-term liabilities . . . . . . . . . . . . . 63,266 70,478 63,854
---------- ---------- ----------
COMMITMENTS AND CONTINGENCIES . . . . . . . . . . . . . . . . . . - - -
---------- ---------- ----------
Total liabilities . . . . . . . . . . . . . . . . . . . . . 924,804 943,755 981,108
---------- ---------- ----------
SHAREHOLDERS' EQUITY:
Common stock - $0.01 par value - authorized shares,
50,000; issued and outstanding shares, 28,362 at
September 30, 1996, and 28,356 at December 31, 1995
and September 30, 1995 . . . . . . . . . . . . . . . . . . . 284 283 283
Preferred stock . . . . . . . . . . . . . . . . . . . . . . . . - - -
Capital in excess of par value . . . . . . . . . . . . . . . . . 72,013 71,945 71,945
Retained earnings . . . . . . . . . . . . . . . . . . . . . . . 44,073 9,258 61,480
---------- ---------- ----------
Total shareholders' equity . . . . . . . . . . . . . . . . 116,370 81,486 133,708
---------- ---------- ----------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY . . . . . . . . . . . . $1,041,174 $1,025,241 $1,114,816
========== ========== ==========
</TABLE>
* Condensed from audited financial statements.
See notes to condensed consolidated financial statements.
4
<PAGE> 7
ZEIGLER COAL HOLDING COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Amounts in thousands)
<TABLE>
<CAPTION>
Nine Months Ended
September 30,
------------------
1996 1995
(Unaudited) (Unaudited)
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 39,778 $ 39,591
-------- --------
Adjustments for differences between net income and cash
flows from operating activities:
Depreciation, depletion and amortization . . . . . . . . . . . . 45,163 51,501
Deferred income taxes . . . . . . . . . . . . . . . . . . . . . . 15,287 2,840
Postretirement benefits . . . . . . . . . . . . . . . . . . . . . (10,751) 1,500
Pneumoconiosis benefits . . . . . . . . . . . . . . . . . . . . . (1,367) (14,133)
Mine closing costs . . . . . . . . . . . . . . . . . . . . . . . (5,027) (7,842)
Stock appreciation units . . . . . . . . . . . . . . . . . . . . (10,732) (383)
Proceeds from contract settlement . . . . . . . . . . . . . . . . - 45,500
Net gain on contract settlement . . . . . . . . . . . . . . . . . - (13,238)
Other noncash items . . . . . . . . . . . . . . . . . . . . . . . 2,344 7,684
Changes in working capital components:
Decrease in receivables . . . . . . . . . . . . . . . . . . . 9,480 17,498
Decrease in inventories . . . . . . . . . . . . . . . . . . . 8,233 959
(Increase) decrease in other current assets . . . . . . . . . (4,272) 553
Decrease in accounts payable - trade . . . . . . . . . . . . (9,481) (17,798)
Increase in deferred revenue . . . . . . . . . . . . . . . . 7,610 10,204
Increase in accrued expenses and other current
liabilities . . . . . . . . . . . . . . . . . . . . . . . 15,966 13,795
-------- ---------
Total decrease in working capital . . . . . . . . . . . . 27,536 25,211
-------- ---------
Total adjustments to net income . . . . . . . . . . . . . . . . . . 62,453 98,640
-------- ---------
Net cash provided by operating activities . . . . . . . . . . . . . 102,231 138,231
-------- --------
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant and equipment . . . . . . . . . . . . . . (19,867) (37,895)
Cash paid for sale of Indiana assets . . . . . . . . . . . . . . . . . (7,000) -
Proceeds from sales of property, plant and equipment . . . . . . . . . 4,407 2,962
-------- ---------
Net cash used in investing activities . . . . . . . . . . (22,460) (34,933)
--------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from common stock issued under stock option plan . . . . . . 68 -
Net repayments of long-term debt . . . . . . . . . . . . . . . . . . . - (92,288)
Payment of dividends . . . . . . . . . . . . . . . . . . . . . . . . . (4,254) (4,254)
--------- ---------
Net cash used in financing activities . . . . . . . . . . . . (4,186) (96,542)
--------- ---------
NET INCREASE IN CASH AND CASH EQUIVALENTS . . . . . . . . . . . . . . . . 75,585 6,756
CASH AND CASH EQUIVALENTS, BEGINNING . . . . . . . . . . . . . . . . . . 13,119 15,583
-------- --------
CASH AND CASH EQUIVALENTS, ENDING . . . . . . . . . . . . . . . . . . . . $ 88,704 $ 22,339
======== ========
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Cash paid for interest . . . . . . . . . . . . . . . . . . . . . . . . $ 12,826 $15,700
Cash paid (received) for income taxes, net of refunds . . . . . . . . (3,078) 8,063
</TABLE>
See notes to condensed consolidated financial statements.
5
<PAGE> 8
ZEIGLER COAL HOLDING COMPANY AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
1. BASIS OF PRESENTATION
The accompanying condensed consolidated financial statements of Zeigler
Coal Holding Company and subsidiaries (the "Company") as of September 30, 1996
and 1995 and for the three and nine month periods then ended, and the notes
thereto, are unaudited and do not include all of the disclosures required under
generally accepted accounting principles. However, in the opinion of
management, all adjustments (consisting only of normal recurring adjustments)
which are necessary for a fair presentation of the financial statements have
been included. These financial statements should be read in conjunction with
the audited consolidated financial statements as of December 31, 1995 and for
the year then ended.
The results of operations for the three and nine month periods ended
September 30, 1996 are not necessarily indicative of the results to be expected
for the full year.
2. INVENTORIES
Inventories have been valued using the average cost method and are stated
at the lower of cost or market.
3. NET INCOME PER COMMON SHARE
Net income per common share is determined by dividing the weighted average
number of common shares outstanding during the period into net income. Common
share equivalents, in the form of stock options, are excluded from the
calculations since they have no material dilutive effect on per share figures.
4. CONTINGENCIES
See Part II, Item 1., "Legal Proceedings".
5. RECLASSIFICATIONS
Certain prior year amounts have been reclassified to conform with the
current year presentation.
6
<PAGE> 9
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
"Safe Harbor" Statement under the Private Securities Litigation Reform
Act of 1995 - The following "Management's Discussion and Analysis of Financial
Condition and Results of Operations" contains forward-looking statements which
are subject to risks and uncertainties inherent in the Company's business. The
Company's actual results could differ materially from those anticipated in
these forward-looking statements as a result of certain factors, including
those set forth herein and elsewhere in documents filed with the Securities and
Exchange Commission, including, without limitation, the Company's Forms 10-K
and 10-Q.
The Company's operations are subject to factors which can negatively
or positively affect the Company's results, including weather, unexpected
maintenance problems, variations in coal seam thickness, amount of overburden,
rock and other natural materials, disruption of transportation services, labor
problems, disputes and/or interruption of deliveries under coal contracts due
to circumstances affecting the customer, regulatory uncertainties, legal
proceedings, and other conditions.
RESULTS OF OPERATIONS
THREE AND NINE MONTHS ENDED SEPTEMBER 30, 1996 AS COMPARED TO THE
THREE AND NINE MONTHS ENDED SEPTEMBER 30, 1995
SUMMARY OF FINANCIAL RESULTS
Reported results for each of the periods presented have contained
special items that could mask the results of the Company's operations and
trends that may have implications for future periods. The following table
shows the impact of special items on the results of each of the periods (per
share).
<TABLE>
<CAPTION>
Quarter Ended Nine Months Ended
September 30, September 30,
-------------- --------------
1996 1995 1996 1995
---- ---- ---- ----
<S> <C> <C> <C> <C>
REPORTED NET INCOME . . . . . . . . . . . . . . . . . . . . . . . . . $.60 $.44 $1.40 $1.40
Less:
Proceeds from contract settlement . . . . . . . . . . . . . . . - - - (1.20)(1)
Add:
Asset impairments and accelerated mine closings . . . . . . . . - - - .85 (1)
Revaluation of stock appreciation units (SAUs) . . . . . . . . . .01(2) - .05(2) -
---- ---- ----- -----
NET INCOME, EXCLUDING SPECIAL ITEMS . . . . . . . . . . . . . . . . . $.61 $.44 $1.45 $1.05
</TABLE>
(1) In the quarter ended June 30, 1995, the Company settled a contract
dispute with Southern Indiana Gas & Electric Company (SIGECO). As
part of the settlement, the coal supply contract with SIGECO was
terminated three years ahead of schedule and, in return, SIGECO paid the
Company $45.5 million ($1.20 per share after taxes). The Company then
closed the supplying mine, Old Ben Mine #1 in Indiana, and reduced the
carrying amount of the mine and certain related properties supporting the
SIGECO contract to their net realizable values. The resulting charge to
earnings amounted to $32.3 million ($.85 per share after taxes) which
consisted of asset write-downs totaling $15.8 million and accelerated
mine closing and reclamation liabilities of $16.5 million.
(2) For the quarter ended September 30, 1996, the Company recorded a $.5
million pretax charge on revaluation of the liability for SAUs. This
charge reflects the $1.25 per share, or 7.8%, increase in the market
price of the Company's common stock since June 30, 1996. For the same
period in 1995, the Company recorded a credit of $.2 million. For the
nine months ended September 30, 1996, the Company recorded a $1.8 million
pretax revaluation charge resulting from the $3.38 per share, or 24.3%,
increase in the market price of the Company's common stock since December
31, 1995. The Company recorded a net charge of $.2 million for the nine
months ended September 30, 1995.
7
<PAGE> 10
Excluding the preceding special items, net income for the three and
nine months ended September 30, 1996 increased $5.1 million, or $.17 per share,
and $11.3 million, or $.40 per share, respectively. The main factors for these
increases were higher gross margins on coal sales, curtailment of
postretirement medical benefits, lower interest costs, and a lower effective
tax rate. These improvements were partially offset by a nonrecurring 1995
reduction in the liability for pneumoconiosis benefits and increased costs at
Old Ben Mine #20 in West Virginia.
COAL OPERATIONS
COAL SALES - The decrease in coal sales for both the three and nine
months ended September 30, 1996 resulted primarily from the Company's strategic
shift from high sulfur Midwestern coal toward lower sulfur, higher margin coal.
For the quarter ended September 30, 1996, sales volume, including
purchased and brokered coal, decreased .8 million tons, or 8.3%. This decrease
primarily reflects a .7 million ton decline in coal produced in the Company's
Midwestern mines resulting from the closing of Old Ben Mine #24 and Old Ben
Mine #1, and the idling of Old Ben Mine #11. Volume was further reduced by a
.4 million ton decline in the Company's Powder River Basin (PRB) mines because
of lower spot sales. These declines were partially offset by a .3 million ton
increase in the Company's Central Appalachian mines. The average sales price
per ton was $21.19 in the third quarter of 1996, an increase of $1.32 per ton,
or 6.6%. This increase reflects lower spot sales in the weak Midwest high
sulfur coal market and increased sales of higher-priced low sulfur coals in
Central Appalachia.
For the nine months ended September 30, 1996, sales volume declined 1.6
million tons, or 5.7%, mainly due to a 1.8 million ton reduction in coal
produced in the Company's Midwestern mines related to the closing or idling of
the three mines. Sales tonnage in the Company's Central Appalachian mines was
unchanged from 1995 while volume rose .2 million tons in the Company's PRB
mines. The average sales price per ton declined $.13 per ton, or .6%, to
$20.33 per ton. This decrease resulted from a contract price reopener and a
heavier mix of lower-priced PRB sales. These declines were partially offset by
reduced spot sales in the Midwest.
COST OF COAL SALES - For the quarter ended September 30, 1996, cost of
coal sales declined $10.5 million, or 5.9%, largely because of reduced sales
volume partially offset by increased costs at Old Ben Mine #20. The average
cost of sales per ton rose $.54 per ton, or 2.9%, to $19.07 per ton, primarily
due to the high costs at Old Ben Mine #20. In part, these costs were caused by
extremely poor roof conditions and a thinning coal seam. After these
conditions unexpectedly and severely worsened in August and September 1996, the
mine was declared unsafe and was closed on October 11, 1996. Loss
contingencies and other accruals associated with the early closing, totaling
$9.9 million, were recorded in the quarter. Also during the quarter, the
Company increased its workers' compensation liability and recognized other loss
contingencies by an aggregate amount of $5.5 million related to the December
1996 closings of Old Ben Mine #26 and the Spartan mine in southern Illinois.
Excluding the $9.9 million and $5.5 million charges discussed above, the
average cost of sales for the third quarter declined $1.21 per ton, or 6.5% to
$17.32 per ton. This improvement reflects a significant reduction in the cost
of serving a contract with Carolina Power and Light Company (CP&L) by idling
Wolf Creek Collieries Company Mine #4 and buying the coal from other producers
in Central Appalachia, a cost reduction at Marrowbone Development Company
resulting from better operating conditions, and lower costs at Old Ben Mine
#26. These factors were partially offset by higher costs in the Company's PRB
mine due to reduced production volume and the impact of the higher selling
prices on sales taxes and royalties.
For the nine months ended September 30, 1996, the cost of coal sales
declined $47.8 million, or 9.4%, due to lower sales volume and cost reductions
discussed below. The average cost of sales per ton decreased $.68 per ton, or
3.7%, to $17.62 per ton. This improvement reflects savings from closing Wolf
Creek Mine #4 and outsourcing one of the CP&L contracts, lower production costs
at Old Ben Mine #26 as explained above, and unusually high operating costs at
Old Ben Mine #24 in 1995. These factors were partially offset by the third
quarter accruals at Old Ben Mine #20, Old Ben Mine #26 and the Spartan mine as
described above.
COSTS AT INACTIVE PROPERTIES - Costs at inactive properties for the
three and nine months ended September 30, 1996 declined $15.5 million and $11.8
million, respectively. This reduction reflects a $16.3 million third quarter
curtailment of the postretirement benefit obligation as a result of the
Company's strategic shift from the weak high sulfur coal market in the
Midwest. The majority of the curtailment gain occurred when former Old Ben
employees found employment with other coal operators, primarily Kindill Mining,
Inc. (Kindill) in Indiana (see following paragraph). The remainder of the gain
resulted from the early closing of Old Ben Mine #24 in Illinois. Excluding
this gain, costs at inactive properties for the three and nine months ended
September 30, 1996 increased by $.8 million and $4.5 million, respectively,
mainly due to the idling of Wolf Creek Mine #4 and Old Ben Mine #11, and the
closing of Old Ben Mine #24. These increases were partially offset by reduced
costs at Old Ben Mine #25 after donation of the mine to the National Museum of
Coal Mining.
8
<PAGE> 11
On February 12, 1996, Old Ben Coal Company sold a majority of its
assets in Indiana to Kindill. These assets had a combined book value of $13.4
million and included Old Ben Mine #1 and Old Ben Mine #2, along with various
other coal properties and interests. The Company also agreed to make cash
payments to Kindill of $7.0 million in 1996 and $4.0 million (subject to
certain adjustments) in 1997. In exchange, Kindill assumed associated
reclamation liabilities, estimated at approximately $23.4 million. This sale
was completed on April 30, 1996 after Kindill secured the required mining
permits. The sale of these assets did not have a material effect on current
income. However, the transaction may have a positive impact on the Company's
future cash flows primarily as a result of lower reclamation expenditures.
REDUCTION IN ACCRUED PNEUMOCONIOSIS BENEFITS - In the third quarter of
1995, the Company reduced the liability for pneumoconiosis benefits based on
lower actuarial estimates. Those estimates reflected favorable claims
experience and lower projected future claims.
INCOME FROM OTHER OPERATIONS
OTHER REVENUES - Other revenues declined by $.3 million in the third
quarter of 1996 primarily due to the timing of farm and timber sales. For the
nine months ended September 30, 1996, other revenues rose $2.4 million due to
sales of nonstrategic land assets in Indiana, increased terminal revenues
attributable to higher European imports of U.S. coal, and higher coal leaseout
revenue.
OTHER COSTS AND EXPENSES - Other costs and expenses increased for the
third quarter 1996 largely due to the scheduled expiration of Department of
Energy (DOE) cofunding for Encoal Corporation's liquids from coal (LFC)
demonstration plant. For the first nine months of 1996, increased other costs
and expenses primarily reflect higher coal throughput at the Company's
import/export terminals, and expiration of the DOE cofunding.
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES
Corporate selling, general and administrative expenses for the three
and nine months ended September 30, 1996 increased due to expanded business
development activities and higher insurance costs, partially offset by lower
legal fees.
NET INTEREST EXPENSE
Net interest expense decreased for the three and nine months ended
September 30, 1996 resulting from a $50.0 million reduction in long-term debt
since June 30, 1995. This debt reduction reflected the use of 1995 SIGECO and
CP&L settlement proceeds in addition to strong operating cash flows.
INCOME TAXES
Lower income taxes in the third quarter of 1996 reflect a 6.0%
reduction in the effective tax rate mainly due to use of net operating loss
carryforwards partially offset by higher pretax earnings. The reduction in
income taxes for the first nine months of 1996 resulted from the lower
effective tax rate and reduced pretax earnings.
LIQUIDITY AND CAPITAL RESOURCES
The Company has generally satisfied its working capital requirements,
its capital expenditure requirements (excluding major acquisitions), its
quarterly dividend payments, and scheduled debt repayments from its operating
cash flow. The Company believes that cash generated from operations will
continue to be sufficient to meet its working capital requirements, planned or
anticipated capital expenditures (excluding major acquisitions), scheduled debt
repayments, and other commitments. If for any reason, such as acceleration of
a major mine development or adverse operating conditions, such operating cash
flow is not sufficient, the Company has the capacity to borrow under its credit
agreement. A major acquisition may require alternative financing including,
without limitation, refinancing certain of the Company's existing debt, new
credit financing, or the sale of additional capital stock.
9
<PAGE> 12
The decrease from 1995 in cash provided by operating activities before
changes in working capital reflects the $45.5 million SIGECO cash settlement in
1995, and higher 1996 SAU payments totaling $12.5 million (of which $12.0
million represented payments on SAU's that became fully vested in 1996). These
decreases were partially offset by an $11.1 million reduction in income tax
payments because of lower pretax earnings and the use of tax loss
carryforwards, a $6.0 million reimbursement received from Shell Oil Company,
and a $3.2 million reduction in mine closing payments reflecting the sale of
certain Old Ben Coal Company properties in Indiana. The remaining $.6 million
cash decrease consists of various individually immaterial items.
Net cash provided by changes in working capital is primarily
attributable to a $16.0 million increase in accrued expenses and other current
liabilities chiefly related to the closings of Old Ben Mine #20, Old Ben Mine
#26 and Old Ben's Spartan mine and a liability associated with the sale of
certain of Old Ben Coal Company's Indiana assets to Kindill, a $9.5 million
timing-related decrease in receivables, a $7.6 million increase in deferred
revenue due to the CP&L settlement at Wolf Creek and the renegotiated CP&L
contract at Marrowbone Development Company, and an $8.2 million decrease in
inventories resulting from the idling of Old Ben Mine #24 and lower production
at Old Ben Mine #20. These increases were partially offset by a $9.5 million
decrease in accounts payable - trade primarily attributable to lower production
caused by the idling or closing of four mines, and a $4.3 million increase in
other current assets relating to the timing of payments for insurance premiums
and income taxes receivable.
Cash used for investing activities primarily consisted of capital
expenditures for maintaining current production levels and improving efficiency
and a $7.0 million payment to Kindill in connection with the 1996 sale of
certain Old Ben Coal Company's assets in Indiana. Capital expenditures for
1996 are expected to total between $30.0 to $35.0 million, including $12.0
million of planned development capital for the new North Rochelle mine in the
PRB (see below "Certain Other Factors Affecting Future Reported Earnings -
Coal Segment - North Rochelle").
Cash used for financing activities represent dividend payments in both
years and net repayments of long-term debt in 1995.
CERTAIN OTHER FACTORS AFFECTING FUTURE REPORTED EARNINGS
COAL SEGMENT
Contract extensions and contract expirations
Many of the Company's long-term contracts contain extension options.
These options permit the Company to extend contracts for an additional period
if both parties reach agreement on certain terms and conditions. Triton Coal
Company has effectively exercised such an option on a contact to supply Western
Farmers Electric Cooperative (Western Farmers). The old contract, which was to
expire in December 1996, was replaced with a new contract that extends through
December 2011 at an annual commitment of 1.5 million tons. The new sales price
effective January 1, 1997 is approximately $10.00 per ton lower than the price
in 1996. Under the new contract, the coal is to be sourced from Triton's
planned North Rochelle mine in Wyoming provided the mine is producing coal on
or before January 1, 1999. Prior to that date, the coal can be supplied from
Triton's Buckskin mine if Western Farmers takes delivery on the Burlington
Northern Railroad. Triton's Buckskin mine does not expect to supply coal under
this contract in 1997.
The Company has a long-term contract to supply the Tennessee Valley
Authority with 1.4 million tons of coal per year through December 1996.
Revenues from this contract are expected to total approximately $35.0 million
in 1996. This contract expires December 31, 1996.
Contract renegotiations
The Company maintains ongoing discussions with its principal coal
customers regarding the possible restructuring of coal supply agreements along
mutually satisfactory lines. The outcome of these discussions and their
impact, if any, on future earnings cannot be reasonably determined at the
present time.
Carolina Power & Light Company - In July 1996, Marrowbone Development
Company and CP&L revised and restated their coal supply agreement, as reported
in the Company's Current Report on Form 8-K dated July
10
<PAGE> 13
22, 1996 and filed with the Securities and Exchange Commission on August 6,
1996. In addition, CP&L entered into a new agreement with Franklin Coal
Sales Company, the Company's sales and marketing subsidiary. The revised
agreement and the new agreement run through 2006 and provide for additional
business opportunities, quality and sourcing flexibility, and a problem-solving
mechanism to resolve quality variations.
Cajun Electric Power Cooperative, Inc.
On September 30, 1996, Louisiana Generating LLC, of which a subsidiary
of the Company is a member, executed an Amended and Restated Asset Purchase and
Reorganization Agreement to purchase substantially all of the non-nuclear
assets of Cajun Electric Power Cooperative, Inc. See Part II, Item 5 for
further discussion.
North Rochelle
The Company announced in February 1996, the full-scale development of
Triton Coal Company's North Rochelle mine in the southern Powder River Basin.
Since that time Triton has purchased and is moving dragline overburden removal
equipment, has proceeded with production of diligence tonnage, has progressed
with permitting, and has begun construction work on the mine. Triton continues
to talk with potential customers to evaluate and analyze the market in an
effort to time North Rochelle's production to best meet a firming market and
peak customer demand for this coal. At this time, Triton estimates full
production at North Rochelle to begin in late 1998.
POWER SEGMENT
EnerZ Corporation
On September 26, 1996, the Company announced the formation of a new
subsidiary, EnerZ Corporation, a Delaware corporation, to take advantage of
emerging market opportunities growing out of utility deregulation. EnerZ's
objectives are to: ( 1) develop an energy marketing unit to enhance return on
the Company's physical assets, (2) provide return-enhancing services to other
owners of physical resources, (3) develop risk management products or services
to stabilize costs or returns for distributors and generators and to help
customers hedge risk, and (4) develop into a retail marketer specializing in
aggregating commercial or residential consumer demands. Initial capital for
EnerZ Corporation is expected to include an equity contribution of $10.0
million and a $15.0 million letter of credit. On October 21, 1996, the Federal
Energy Regulatory Commission issued a letter order granting power marketer
status, effective as of November 15, 1996, to EnerZ Corporation under the
Federal Power Act.
TECHNOLOGY SEGMENT
Encoal Corporation / TEK-KOL
On October 22, 1996, Encoal Corporation (Encoal), a wholly-owned
subsidiary of the Company, announced that it has begun permitting work for a
possible full-scale LFC plant in Wyoming. Encoal is conducting permitting and
engineering work as part of early planning to develop a full-scale LFC
upgrading facility in Campbell County, Wyoming. A full-scale plant would have
the capacity to upgrade approximately 6 million tons of feedstock coal per
year. There are no assurances as to when, and if, such a plant would be built
or placed into operation.
The LFC technology is owned and licensed by TEK-KOL Partnership, a
partnership between a subsidiary of the Company and SGI International, the
inventor of the technology. The LFC technology converts low-rank coals into
two primary products, a low-sulfur clean coal product called Process Derived
Fuel (PDF) that has a higher heating value than the source coal, and Coal
Derived Liquid (CDL), a low-sulfur hydrocarbon liquid with distillate
properties. By increasing the value of low-rank coal, the LFC process may open
up additional markets for these coals.
In addition to a Wyoming facility, TEK-KOL is in discussions regarding
LFC licensing for full-scale plants overseas. To date, TEK-KOL has tested and
analyzed 10 domestic and 21 foreign coals to determine the most promising
candidate coals for LFC processing. As a result of these tests, two
feasibility studies for full-scale commercial plants utilizing feedstock coal
from reserves owned by two separate Indonesian companies have been completed in
1996, and other international opportunities are being explored.
11
<PAGE> 14
OTHER
New accounting principles (stock-based compensation)
In October 1995, the Financial Accounting Standards Board issued SFAS
No. 123 "Accounting for Stock-Based Compensation," which requires adoption in
1996. The new standard defines a fair value method of accounting for stock
options and similar equity instruments. Under the fair value method,
compensation cost is measured at the grant date based on the fair value of the
award and is recognized over the service period, which is usually the vesting
period. Pursuant to the new standard, companies are encouraged, but not
required, to adopt the fair value method of accounting for employee stock-based
transactions. However, companies are also permitted to continue to account for
such transactions under Accounting Principles Board Opinion No. 25, "Accounting
for Stock Issued to Employees," but would be required to disclose in a note to
the financial statements the pro forma net income and, if presented, earnings
per share as if the Company had applied the new method of accounting. The
accounting requirements of the new method are effective for all employee awards
granted after the beginning of the fiscal year of adoption. The Company has
elected not to change to the fair value method.
Revenue estimate for 1996
As a result of the mine closings and contract price changes discussed
above, the Company expects its coal production and total revenues to be lower
in 1996 compared to 1995. Based on several key assumptions regarding prices,
demand, production levels, contract renegotiations and various other matters,
management estimates that total revenues in 1996 will range between $725.0 and
$750.0 million and that coal sales volume will total between 33.0 and 34.0
million tons. Because such estimates are based on many factors outside the
control of the Company, actual 1996 revenues and coal tonnage could be
significantly different than the current estimates.
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
The Company incorporates herein by reference the "Legal Proceedings"
section beginning on page 19, and Note 15, beginning on page 61, of its Form
10-K for the fiscal year ended December 31, 1995.
Shareholder Suits - On November 8, 1994, a shareholder of the Company
filed a class action suit, Barish, et al. v. Zeigler Coal Holding Co., et al.,
against the Company and three of its officers in U.S. District Court for the
Southern District of Illinois. The amended complaint in the matter contained
two counts and generally alleged that the Company failed to disclose material
facts regarding its long-term supply contracts and a related dispute with
Carolina Power & Light Company. The first count pled a claim under Sections
10(b) and 20 of the Securities Act of 1934 and SEC Rule 10b-5 alleging that the
Company and the individual defendants issued false and misleading public
statements in the initial public offering of September 29, 1994 and in a press
release on October 28, 1994. The second count pled a claim under Sections 11
and 15 of the Securities Act of 1933 alleging that the Company made material
misstatements and omissions in the registration statement issued in connection
with the September 29, 1994 initial public offering. The complaint sought
damages in an unspecified amount on behalf of all persons who purchased the
common stock of Zeigler in the public offering and on the open market from
September 29, 1994 to November 3, 1994. On March 10, 1995, a second class
action suit, Greenfield v. Reilly, et al., was filed in the U.S. District Court
for the Southern District of Illinois arising out of the same events and
transactions as the Barish action. In addition to the claims asserted against
the Company and certain of its officers in the Barish action, the complaint
asserted claims under Section 12(2) of the 1933 Act against the Company's lead
underwriters for its 1994 initial public offering and against a purported class
of all other underwriters who participated in the offering. Pursuant to the
terms of an underwriting agreement, the Company may have an obligation to
indemnify the underwriters for the claims asserted against them. The Company
has given notice of these suits to its carrier under a Directors and Officers
Insurance and Company Reimbursement Policy and a related securities offering
entity coverage endorsement.
The two suits were subsequently consolidated, and the plaintiffs filed
an amended consolidated complaint. The Company and the individual defendants
have denied the allegations that they violated the federal securities laws and
have vigorously defended these cases. The court has previously denied
12
<PAGE> 15
defendants' motion to dismiss and the plaintiffs' motion for certification of
the case as a class action. The Company and its insurer have now reached an
agreement with plaintiffs' counsel to settle the claims of all members of the
putative class. This settlement, which is subject to court approval, will not
have a material adverse effect on the Company's consolidated results of
operations or financial position.
Cajun Electric Power Cooperative - On December 21, 1994, Cajun Electric
Power Cooperative Inc. ("Cajun") filed with the U.S. Bankruptcy Court for the
Middle District of Louisiana (the "Bankruptcy Court") for voluntary
reorganization under Chapter 11 of the U.S. Bankruptcy Code. Triton Coal
Company has a requirements contract (the "Triton Contract") with Cajun through
Western Fuels Association, Inc., with a term extending through the life of Big
Cajun Plant No. 2. During 1995, Triton Coal Company shipped 5.8 million tons
of coal to Cajun (representing 3% of the Company's total consolidated
revenues), while 1994 shipments to Cajun totaled 5.5 million tons. To date,
neither shipments to Cajun nor payments have been affected by the bankruptcy
proceeding. The price for coal sold under the Triton Contract is at or near the
market price for this coal. The Triton Contract provides for a price reopener
effective January 1, 1998.
An Appellate Court affirmed a District Court's ruling that a
court-appointed trustee will manage Cajun's affairs during the bankruptcy. The
trustee presented a plan for reorganization to the Bankruptcy Court on May 10,
1996. At this time, it appears likely that the trustee will reject the Triton
Contract. In the event that the contract is rejected, it may be necessary for
Triton to find other markets for this coal, including sales to the new operator
of Cajun's coal fired units.
As discussed below in Part II, Item 5, Louisiana Generating LLC (an
affiliate of the Company, Southern Electric International, Inc., and NRG
Energy, Inc.) has executed an Amended and Restated Asset Purchase and
Reorganization Agreement to purchase substantially all of Cajun's non-nuclear
assets. This Agreement is subject to Bankruptcy Court approval including
evaluation of competing offers and a number of other conditions. As a result
of Louisiana Generating's entering into this Agreement, Western Fuels
Association, Inc. has formally requested certain assurances regarding Triton
Coal Company's performance under the Triton Contract and informed the Company
that it reserves the right to assert certain claims against Triton Coal Company
if the trustee rejects the Triton Contract.
Janet Saad-Cook et al. v. Zeigler Coal Holding Company and R. & F. Coal
Company - In March, 1995, plaintiff filed a lawsuit against the Company and its
subsidiary, R. & F. Coal Company. The complaint includes several causes of
action based on alleged actions of the defendant companies involving fraud,
deceit, misrepresentation, tortuous breach of contract with respect to two coal
mining leases made among the plaintiffs and R. & F. Coal Company. In April
1996, plaintiffs filed an Amended Complaint with Jury Trial Demanded in which
plaintiffs eliminated their allegations that the defendants' behavior violated
the U.S. Racketeer Influenced and Corrupt Organizations Act but continued to
allege several causes of action involving fraud, deceit misrepresentation,
conversion, tortuous breach of contract, and the covenant of good faith and
fair dealing. The defendant companies have denied the allegations in the
complaint, believe they have meritorious defenses to plaintiff's claims, and
intend to defend vigorously against the claims. The Company believes that
Shell Oil Company ("Shell") is obligated to indemnify the Company against any
loss (over certain minimum amounts) that the Company may incur as a result of
plaintiff's claims in the litigation and has given Shell notice thereof in
accordance with the terms of the purchase agreement under which the Company
acquired Shell Mining companies. On March 28, 1996, the Court denied a motion
made by the Company and R. & F. to dismiss this suit. The Company believes that
ultimate resolution of the claims in the lawsuit will have no material adverse
effect on the Company's consolidated results of operations or financial
position.
Other - Various lawsuits and claims, including those involving ordinary
routine matters incidental to its business, to which the Company and its
subsidiaries are a party, are pending, or have been asserted, against the
Company. Although the outcome of these matters cannot be predicted with
certainty, management believes that their disposition will not have materially
adverse effects on the Company's consolidated results of operations or
financial position.
13
<PAGE> 16
ITEM 5. OTHER INFORMATION
CAJUN ELECTRIC POWER COOPERATIVE, INC.
On September 30, 1996, Louisiana Generating LLC, a Delaware limited
liability company ("Generating") (the three members of which are Zenergy, Inc.,
a Delaware corporation that is a wholly-owned subsidiary of the Company,
Southern Energy - Cajun, Inc. a Delaware corporation that is a wholly-owned
subsidiary of Southern Electric International, Inc. ("SEI"), and NRG Energy,
Inc., a Delaware corporation ("NRG")), the Company, SEI, NRG and Ralph R. Mabey
(the "Trustee"), as Chapter 11 Trustee of Cajun Electric Power Cooperative,
Inc. ("Cajun"), executed an Amended and Restated Asset Purchase and
Reorganization Agreement (the "Cajun Purchase Agreement") pursuant to which
Generating agreed to purchase substantially all of the non-nuclear generating
assets, transmission assets and certain other assets of Cajun (collectively
"Acquired Assets"). Pursuant to the Cajun Purchase Agreement, Generating has
agreed to purchase the Acquired Assets for a purchase price of approximately
$1.09 billion, subject to adjustment for interest rate fluctuations (the "Cajun
Acquisition"). Pursuant to the Cajun Purchase Agreement, Generating will
assume no liabilities of Cajun other than post-closing obligations under
contracts specifically assumed by Generating, certain indemnity obligations
under "safe-harbor leases" assumed by Generating and environmental liabilities
that attach to the owner of any of the Acquired Assets by operation of law.
Also, on June 15, 1996, Generating accepted an underwritten commitment from a
major institutional lender for non-recourse financing for the Cajun Acquisition
in the amount of $910 million. This financing commitment is subject to
numerous conditions, including the lender's due diligence.
The consummation of the Cajun Acquisition is subject to a number of
conditions, including, without limitation, the entering of a final and
non-appealable order (the "Confirmation Order") by the United States Bankruptcy
Court for the Middle District of Louisiana (the "Bankruptcy Court") confirming
the Plan of Reorganization for Cajun proposed by the Trustee that incorporates
the terms and conditions of the Cajun Purchase Agreement (the "Trustee's
Plan"), the receipt of all regulatory approvals (including, without limitation,
the granting by the Federal Energy Regulatory Commission ("FERC") of exempt
wholesale generator status to Generating and approval by FERC of the rates
specified in the proposed wholesale power agreement pursuant to which
Generating will provide Cajun (as reorganized pursuant to the Trustee's Plan)
with a supply of power sufficient to fulfill all of Cajun's member
cooperatives' respective energy requirements), and other conditions customary
for transactions such as the Cajun Acquisition. The Cajun Purchase Agreement
does not contain a financing contingency. In the event the Cajun Acquisition
is not consummated solely as a result of a material breach or breaches by
Generating of its obligations under the Cajun Purchase Agreement, Generating
will be obligated to pay the Trustee liquidated damages: of (i) $7.5 million
if such breach occurs prior to the date on which the Bankruptcy Court issues
the Confirmation Order; or (ii) $20.0 million if such breach occurs on or after
the date on which the Bankruptcy Court issues the Confirmation Order (30% of
which must be paid by the Company if Generating does not promptly pay such fee
when due).
The Cajun Purchase Agreement also contains certain provisions
protecting Generating in the event the Cajun Acquisition is not consummated.
First, Generating, the Company and NRG collectively are entitled to receive
from Cajun up to $7.5 million for reimbursement of certain transaction-related
expenses (the "Expense Reimbursement") if the Cajun Acquisition is not
consummated for any reason other than a material default by Generating of its
obligations under the Cajun Purchase Agreement. Second, Generating is entitled
to receive from Cajun a termination fee of $20.0 million (the "Termination
Fee") if the Cajun Acquisition is not consummated because of a material
default, after the Bankruptcy Court issues the Confirmation Order, by the
Trustee or Cajun of its or their obligations under the Cajun Purchase
Agreement. Finally, Generating is entitled to receive from Cajun a break-up
fee of $7.5 million (the "Break-Up Fee") if the Cajun Purchase Agreement is
terminated prior to the date on which the Bankruptcy Court issues the
Confirmation Order for any reason other than a material default by Generating
and, thereafter, substantially all of the Acquired Assets are sold pursuant to
Section 363 of the U.S. Bankruptcy Code (a "Section 363 Sale"), or an
alternative reorganization plan for Cajun is confirmed by the Bankruptcy Court
(an "Alternative Plan"), either of which results in aggregate consideration of
$1 billion or more to the Cajun bankruptcy estate (other than a Section 363
Sale or an Alternative Plan in which the acquirer is Southwestern Electric
Power Company ("SWEPCO") or Enron Capital & Trade Resources Corp. ("Enron") or
one of their respective designated subsidiaries). In no event is Generating
entitled to receive both the Termination Fee and the Break-Up Fee. The
Trustee's or Cajun's obligations to pay the Expense Reimbursement, the
Termination Fee and the Break-Up Fee were approved by the Bankruptcy Court
pursuant to an Order dated August 26, 1996.
In addition to the proposed Trustee's Plan, there are two other
competing reorganization plans for Cajun that have been filed with the
Bankruptcy Court by SWEPCO (a plan that is supported by many of Cajun's member
cooperatives), and Enron (a plan that is supported by Cajun's unsecured
creditor's committee). Because of the uncertainty as to whether or when the
Bankruptcy Court will confirm the Trustee's Plan (especially in light of the
14
<PAGE> 17
competing reorganization plans and the competitive-bidding nature of the
bankruptcy proceeding) and as to whether all of the conditions to consummating
the Cajun Acquisition can be satisfied on or prior to the outside closing date
set forth in the Cajun Purchase Agreement (June 30, 1997), there can be no
assurance that the Cajun Acquisition will be consummated upon the current terms
and conditions of the Cajun Purchase Agreement or any other terms. The
Bankruptcy Court has tentatively scheduled the confirmation hearing to commence
on or about December 15, 1996.
Under the existing agreement regarding Generating, the Company
(through Zenergy, Inc.), SEI (through Southern Energy - Cajun, Inc.) and NRG,
respectively own 30%, 40%, and 30% of the ownership interests in Generating and
are each responsible for their pro rata share of the expenses incurred in
connection with the Cajun Acquisition and the liquidated damages that
Generating would incur if the Cajun Acquisition is not consummated solely as
the result of a material breach by Generating of its obligations under the
Cajun Purchase Agreement. Unless other parties invest in Generating (which
would require the approval of the Company, SEI and NRG), each of the Company,
SEI and NRG would respectively contribute 30%, 40% and 30% of the capital
required by Generating to consummate the Cajun Acquisition and related
financing.
Either the Company or NRG may withdraw from Generating at any time
prior to the consummation of the Cajun Acquisition, provided such withdrawal
will not affect the withdrawing party's responsibility for its share of
expenses and any liquidated damages that Generating may incur (unless such
withdrawal occurs prior to the Bankruptcy Court's confirmation of the Trustee's
plan and the obligation to pay liquidated damages arises after such
confirmation, in which event the withdrawing party will not be responsible for
any liquidated damages). The approval of the Company, SEI and NRG is required
for any change in the terms and conditions of the Cajun Acquisition.
The Company is in the process of developing financing alternatives to
fund its required investment in Generating. If the Cajun Acquisition is
completed, the Company may be required to refinance approximately $199.0
million of its long-term debt. The Company presently does not have any
commitments with respect to funding its investment in Generating or refinancing
its long-term debt.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
A. Exhibits - None
B. A Report on Form 8-K dated July 22, 1996, reporting Item 5 was filed
during the quarter ended September 30, 1996.
15
<PAGE> 18
SIGNATURES
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 hereunto duly authorized.
ZEIGLER COAL HOLDING COMPANY
(Registrant)
November 14, 1996 /s/ Paul D. Femmer
-------------------------------
Paul D. Femmer
Controller
(Principal Accounting Officer
and duly authorized officer)
16
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM CONDENSED
CONSOLIDATED BALANCE SHEETS AND STATEMENTS OF OPERATIONS AS OF SEPTEMBER 30,
1996 AND 1995 AND FOR THE NINE MONTH PERIODS THEN ENDED, AND IS QUALIFIED IN ITS
ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1996
<PERIOD-START> JAN-01-1996
<PERIOD-END> SEP-30-1996
<CASH> 88,704
<SECURITIES> 0
<RECEIVABLES> 57,237
<ALLOWANCES> 2,583
<INVENTORY> 41,713
<CURRENT-ASSETS> 204,662
<PP&E> 1,136,605
<DEPRECIATION> 313,179
<TOTAL-ASSETS> 1,041,174
<CURRENT-LIABILITIES> 137,048
<BONDS> 344,770
0
0
<COMMON> 284
<OTHER-SE> 116,086
<TOTAL-LIABILITY-AND-EQUITY> 1,041,174
<SALES> 533,705
<TOTAL-REVENUES> 556,941
<CGS> 462,487
<TOTAL-COSTS> 460,414
<OTHER-EXPENSES> 31,438
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 17,186
<INCOME-PRETAX> 47,943
<INCOME-TAX> 8,165
<INCOME-CONTINUING> 39,778
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 39,778
<EPS-PRIMARY> 1.40
<EPS-DILUTED> 1.40
</TABLE>
