1
EXHIBIT 99.1
REPORT OF INDEPENDENT ACCOUNTANTS
To the Stockholders and Board of Directors
TransTexas Gas Corporation:
We have audited the accompanying consolidated balance sheet of TransTexas
Gas Corporation as of January 31, 1997 and 1996 and the related consolidated
statements of operations, stockholders deficit and cash flows for the year ended
January 31, 1997, the six months ended January 31, 1996 and each of the two
years in the period ended July 31, 1995. These financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the consolidated financial position of
TransTexas Gas Corporation as of January 31, 1997 and 1996, and the results of
its operations and cash flows for the year ended January 31, 1997, the six
months ended January 31, 1996, and each of the two years in the period ended
July 31, 1995 in conformity with generally accepted accounting principles.
COOPERS & LYBRAND L.L.P.
Houston, Texas
May 1, 1997
2
TRANSTEXAS GAS CORPORATION
CONSOLIDATED BALANCE SHEET
(IN THOUSANDS OF DOLLARS, EXCEPT SHARE AMOUNTS)
JANUARY 31,
------------------------
1997 1996
---------- ----------
ASSETS
Current assets:
Cash and cash equivalents................................. $ 23,561 $ 11,248
Cash restricted for interest (Note 6)..................... 46,000 46,000
Accounts receivable....................................... 78,660 36,251
Receivable from affiliates................................ 3,248 3,697
Inventories............................................... 12,481 11,421
Other current assets...................................... 24,984 50,821
---------- ----------
Total current assets.............................. 188,934 159,438
---------- ----------
Property and equipment...................................... 2,280,880 2,008,068
Less accumulated depreciation, depletion and amortization... 1,434,487 1,292,728
---------- ----------
Net property and equipment -- based on the full cost
method of accounting for gas and oil properties of
which $158,973 and $136,360 at January 31, 1997 and
1996, respectively, were excluded from amortization.... 846,393 715,340
---------- ----------
Due from affiliates......................................... -- 26,846
Other assets, net........................................... 17,825 37,203
---------- ----------
$1,053,152 $ 938,827
========== ==========
LIABILITIES AND STOCKHOLDERS' DEFICIT
Current liabilities:
Current maturities of long-term debt...................... $ 5,787 $ 1,335
Accounts payable.......................................... 28,150 39,745
Accrued liabilities....................................... 83,411 74,756
---------- ----------
Total current liabilities......................... 117,348 115,836
---------- ----------
Long-term debt, less current maturities..................... 8,775 2,541
Production payments, less current portion................... 11,931 31,036
Senior secured notes........................................ 800,000 800,000
Subordinated notes.......................................... 101,092 --
Revolving credit agreement.................................. 26,268 20,365
Deferred revenue............................................ 54,554 32,850
Deferred income taxes....................................... 31,367 40,256
Payable to affiliates....................................... 19,621 15,193
Other liabilities........................................... 32,991 35,190
Commitments and contingencies (Note 12)..................... -- --
Stockholders' deficit:
Common stock, $0.01 par value, authorized 100,000,000
shares, issued and outstanding 74,000,000 shares....... 740 740
Capital deficit........................................... (123,524) (107,040)
Retained earnings (accumulated deficit)................... 31,267 (48,140)
---------- ----------
(91,517) (154,440)
Advances to affiliates.................................... (59,278) --
---------- ----------
Total stockholders' deficit....................... (150,795) (154,440)
---------- ----------
$1,053,152 $ 938,827
========== ==========
The accompanying notes are an integral part of the consolidated financial
statements.
3
TRANSTEXAS GAS CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS
(IN THOUSANDS OF DOLLARS, EXCEPT SHARE AMOUNTS)
SIX MONTHS ENDED
YEAR ENDED JANUARY 31, JANUARY 31, YEAR ENDED JULY 31,
------------------------ ------------------------ -----------------------
1997 1996 1996 1995 1995 1994
---------- ----------- ---------- ----------- ---------- ----------
(UNAUDITED) (UNAUDITED)
Revenues:
Gas, condensate and natural gas
liquids......................... $ 363,459 $ 256,986 $ 124,663 $ 143,304 $ 275,627 $ 302,522
Transportation.................... 34,423 33,518 15,892 19,161 36,787 33,240
Gains on the sale of assets....... 7,856 474 474 -- -- --
Other............................. 609 360 127 52 285 157
---------- ---------- ---------- ---------- ---------- ----------
Total revenues................ 406,347 291,338 141,156 162,517 312,699 335,919
---------- ---------- ---------- ---------- ---------- ----------
Costs and expenses:
Operating......................... 114,453 78,812 38,145 44,605 85,272 90,216
Depreciation, depletion and
amortization.................... 132,453 120,513 60,894 70,345 129,964 113,858
General and administrative........ 45,596 33,025 13,685 12,595 31,935 40,311
Taxes other than income taxes..... 22,566 15,234 7,484 6,288 14,038 13,243
Litigation settlements............ (96,000) (18,300) (18,300) -- -- (1,000)
---------- ---------- ---------- ---------- ---------- ----------
Total costs and expenses...... 219,068 229,284 101,908 133,833 261,209 256,628
---------- ---------- ---------- ---------- ---------- ----------
Operating income.............. 187,279 62,054 39,248 28,684 51,490 79,291
---------- ---------- ---------- ---------- ---------- ----------
Other income (expense):
Interest income................... 5,544 4,733 2,934 912 2,711 1,516
Interest expense.................. (97,007) (81,907) (43,370) (29,971) (68,508) (51,671)
---------- ---------- ---------- ---------- ---------- ----------
Total other income
(expense).................. (91,463) (77,174) (40,436) (29,059) (65,797) (50,155)
---------- ---------- ---------- ---------- ---------- ----------
Income (loss) before income
taxes...................... 95,816 (15,120) (1,188) (375) (14,307) 29,136
Income tax expense (benefit)........ 12,491 (2,700) (416) (131) (2,415) 5,380
---------- ---------- ---------- ---------- ---------- ----------
Income (loss) before
extraordinary item......... 83,325 (12,420) (772) (244) (11,892) 23,756
Extraordinary item -- loss on early
extinguishment of debt, net of tax
(Note 2).......................... -- (56,637) -- -- (56,637) --
---------- ---------- ---------- ---------- ---------- ----------
Net income (loss)............. $ 83,325 $ (69,057) $ (772) $ (244) $ (68,529) $ 23,756
========== ========== ========== ========== ========== ==========
Net income (loss) per share:
Income (loss) before extraordinary
item............................ $ 1.13 $ (0.17) $ (0.01) $ -- $ (0.16) $ 0.33
Extraordinary item................ -- (0.77) -- -- (0.77) --
---------- ---------- ---------- ---------- ---------- ----------
$ 1.13 $ (0.94) $ (0.01) $ -- $ (0.93) $ 0.33
========== ========== ========== ========== ========== ==========
Weighted average number of shares
outstanding....................... 74,000,000 74,000,000 74,000,000 74,000,000 74,000,000 71,105,263
========== ========== ========== ========== ========== ==========
The accompanying notes are an integral part of the consolidated financial
statements.
4
TRANSTEXAS GAS CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
(IN THOUSANDS OF DOLLARS)
SIX MONTHS ENDED
YEAR ENDED JANUARY 31, JANUARY 31, YEAR ENDED JULY 31,
----------------------- ----------------------- ---------------------
1997 1996 1996 1995 1995 1994
--------- ----------- --------- ----------- --------- ---------
(UNAUDITED) (UNAUDITED)
Operating activities:
Net income (loss)............................ $ 83,325 $ (69,057) $ (772) $ (244) $ (68,529) $ 23,756
Adjustments to reconcile net income (loss) to
net cash provided by operating activities:
Extraordinary item......................... -- 56,637 -- -- 56,637 --
Depreciation, depletion and amortization... 132,453 120,513 60,894 70,345 129,964 113,858
Amortization of debt issue costs........... 8,387 3,558 1,295 1,524 3,787 2,818
Accretion of interest on subordinated
notes.................................... 1,647 -- -- -- -- --
Gain on litigation settlement.............. -- (18,300) (18,300) -- -- --
Gains on the sale of assets................ (7,856) (474) (474) -- -- --
Deferred income taxes...................... (8,889) 6,263 (416) (1,483) 5,196 (5,961)
Proceeds from volumetric production
payments................................. 58,621 32,850 32,850 -- -- --
Amortization of deferred revenue........... (36,917) -- -- -- -- --
Changes in assets and liabilities:
Accounts receivable...................... (42,409) (5,604) (12,860) 7,859 15,115 (37,058)
Receivable from affiliates............... 449 380 272 765 873 (1,239)
Inventories.............................. (1,060) (3,229) (3,185) 1,753 1,709 977
Other current assets..................... (2,154) (3,210) (201) (2,193) (5,202) 351
Accounts payable......................... 9,900 (14,150) 3,677 3,006 (14,821) 4,496
Accrued liabilities...................... 31,134 (21,420) (3,843) (6,982) (24,559) 15,082
Transactions with affiliates, net........ (6,825) (17,788) (5,536) 265 (11,987) (721)
Other assets............................. 21,428 20 699 (885) (1,564) (728)
Other liabilities........................ (20,173) 5,163 (1,928) 602 7,693 20,612
--------- --------- --------- --------- --------- ---------
Net cash provided by operating
activities........................... 221,061 72,152 52,172 74,332 94,312 136,243
--------- --------- --------- --------- --------- ---------
Investing activities:
Capital expenditures......................... (340,651) (318,800) (155,886) (106,170) (269,084) (233,390)
Proceeds from the sale of assets............. 92,518 20,500 20,500 -- -- --
Withdrawals from cash restricted for
interest................................... 92,000 44,722 44,722 -- -- --
Increase in cash restricted for interest..... (92,000) (90,722) (46,000) -- (44,722) --
Advances to affiliate........................ (24,750) (4,700) (4,700) -- -- (8,257)
Payment of advances by affiliate............. -- 4,700 4,700 -- -- 8,257
Purchase of production payment from
affiliate.................................. -- -- -- -- -- (5,000)
Production payment by affiliate.............. -- 3,547 -- 844 4,391 609
--------- --------- --------- --------- --------- ---------
Net cash used in investing
activities........................... (272,883) (340,753) (136,664) (105,326) (309,415) (237,781)
--------- --------- --------- --------- --------- ---------
Financing activities:
Principal payments on long-term debt......... (19,135) (20,219) (219) -- (20,000) --
Proceeds from long-term borrowings........... 26,200 13,000 3,000 10,000 20,000 --
Revolving credit agreement, net.............. 5,903 11,664 20,365 8,701 -- --
Issuance of production payments.............. 28,598 49,500 -- -- 49,500 --
Principal payments on production payments.... (45,205) (16,699) (8,833) -- (7,866) --
Issuance of senior secured notes............. -- 800,000 -- -- 800,000 500,000
Retirement of senior secured notes........... -- (542,500) -- -- (542,500) --
Issuance of subordinated notes............... 99,445 -- -- -- -- --
Debt issue costs............................. (9,187) (15,716) (1,258) (452) (14,910) (19,418)
Issuance of common stock..................... -- -- -- -- -- 66,142
Dividend to TransAmerican.................... -- -- -- -- -- (32,960)
Transfer of litigation escrow to affiliate... (22,484) -- -- -- -- --
Restricted cash.............................. -- -- -- -- -- (29,133)
--------- --------- --------- --------- --------- ---------
Net cash provided by financing
activities........................... 64,135 279,030 13,055 18,249 284,224 484,631
--------- --------- --------- --------- --------- ---------
Net transactions with parent company........... -- -- -- -- -- (369,529)
--------- --------- --------- --------- --------- ---------
Increase (decrease) in cash and cash
equivalents.......................... 12,313 10,429 (71,437) (12,745) 69,121 13,564
Beginning cash and cash equivalents............ 11,248 819 82,685 13,564 13,564 --
--------- --------- --------- --------- --------- ---------
Ending cash and cash equivalents............... $ 23,561 $ 11,248 $ 11,248 $ 819 $ 82,685 $ 13,564
========= ========= ========= ========= ========= =========
The accompanying notes are an integral part of the consolidated financial
statements.
5
TRANSTEXAS GAS CORPORATION
CONSOLIDATED STATEMENT OF STOCKHOLDERS' DEFICIT
(IN THOUSANDS OF DOLLARS, EXCEPT SHARE AMOUNTS)
RETAINED
COMMON STOCK EARNINGS TOTAL
------------------- (ACCUMULATED ADVANCES STOCKHOLDERS'
SHARES AMOUNT CAPITAL DEFICIT DEFICIT) TO AFFILIATES EQUITY (DEFICIT)
---------- ------ ----------------- ------------ ------------- ----------------
Balance at July 31, 1993..... 1,000 $ -- $ 1 $ -- $ -- $ 1
Transfer, as adjusted
(Note 1)................ -- -- (142,078) -- -- (142,078)
Effect of stock split...... 68,999,000 690 (690) -- -- --
Issuance of common stock... 5,000,000 50 66,092 -- -- 66,142
Dividend to
TransAmerican........... -- -- (32,960) -- -- (32,960)
Net income................. -- -- 2,595 21,161 -- 23,756
---------- ---- --------- -------- -------- ---------
Balance at July 31, 1994..... 74,000,000 740 (107,040) 21,161 -- (85,139)
Net loss................... -- -- -- (68,529) -- (68,529)
---------- ---- --------- -------- -------- ---------
Balance at July 31, 1995..... 74,000,000 740 (107,040) (47,368) -- (153,668)
Net loss................... -- -- -- (772) -- (772)
---------- ---- --------- -------- -------- ---------
Balance at January 31,
1996....................... 74,000,000 740 (107,040) (48,140) -- (154,440)
Elimination of intercompany
gain on property
purchased from
affiliate............... -- -- -- (3,918) -- (3,918)
Transfer of litigation
escrow to affiliate..... -- -- (22,484) -- -- (22,484)
Contribution of Signal
Capital Holdings
Corporation stock by
affiliate............... -- -- 6,000 -- -- 6,000
Advances to affiliates..... -- -- -- -- (59,278) (59,278)
Net income................. -- -- -- 83,325 -- 83,325
---------- ---- --------- -------- -------- ---------
Balance at January 31,
1997....................... 74,000,000 $740 $(123,524) $ 31,267 $(59,278) $(150,795)
========== ==== ========= ======== ======== =========
The accompanying notes are an integral part of the consolidated financial
statements.
6
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Information With Respect to the Year Ended January 31, 1996 and the Interim
Period
Ended January 31, 1995, is Unaudited)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Organization
TransTexas Gas Corporation (together with its subsidiaries, the "Company"
or "TransTexas") was incorporated in May 1993 for the purpose of operating
certain oil and gas and transmission assets previously operated by TransAmerican
Natural Gas Corporation ("TransAmerican") and certain of its subsidiaries. On
August 24, 1993, the Company issued $500 million in 10 1/2% Senior Secured Notes
due 2000 (the "Prior Notes"), and concurrently certain of these operations were
transferred at predecessor basis pursuant to an agreement among the Company,
TransAmerican and certain of its subsidiaries, and TransAmerican's sole
stockholder (the "Transfer"). As a result of the Transfer, the Company became a
wholly-owned subsidiary of TransAmerican and succeeded to the gas and oil
properties, exploration and development operations, and natural gas gathering
and transportation operations of TransAmerican and certain subsidiaries, except
for specific excluded assets (including accounts receivable) retained by
TransAmerican. The Company is currently an indirect subsidiary of TransAmerican.
TransAmerican and certain subsidiaries emerged from a proceeding under
Chapter 11 of the Bankruptcy Code on October 19, 1987, pursuant to a confirmed
Plan of Reorganization. With the proceeds of the Company's public offering of
the Prior Notes, the Company paid all allowed claims under TransAmerican's Plan
of Reorganization as well as certain other debts of TransAmerican. During 1996,
the Company reclassified approximately $21.6 million of deferred income taxes
payable to capital to properly reflect liabilities of TransAmerican.
TransTexas Transmission Corporation was incorporated in June 1993. In
December 1995, TransTexas Exploration Corporation ("TTEX") was incorporated as a
wholly-owned subsidiary of the Company and is an Unrestricted Subsidiary, as
defined in the Indenture (defined below). In January 1997, TransTexas Drilling
Services, Inc. was incorporated as a wholly-owned subsidiary of the Company.
Change in Fiscal Year
On January 12, 1996, the Board of Directors determined to change the fiscal
year end of the Company to January 31. The consolidated financial statements
include presentation of the year ended January 31, 1997 and the six months ended
January 31, 1996 (the "Transition Period") and the comparable prior year and six
month periods which are unaudited. Certain previously reported financial
information has been reclassified to conform with the current presentation.
Use of Estimates
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date(s) of the financial
statements and the reported amounts of revenues and expenses during the
reporting period(s). The Company's most significant financial estimates are for
amounts based on remaining proved gas and oil reserves (see Note 17) and
contingencies. Actual results could differ from these estimates.
Cash and Cash Equivalents
The Company considers all highly liquid investments purchased with an
original maturity of three months or less to be cash equivalents.
7
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Inventories
The Company's inventories, consisting primarily of tubular goods, are
stated at the lower of average cost or market.
Gas and Oil Properties
The Company uses the full cost method of accounting for exploration and
development costs. Under this method of accounting, the cost for successful as
well as unsuccessful exploration and development activities are capitalized.
Such capitalized costs and estimated future development and reclamation costs
are amortized on a unit-of-production method. Net capitalized costs of gas and
oil properties are limited to the lower of unamortized cost or the cost center
ceiling, defined as the sum of the present value (10% discount rate) of
estimated unescalated future net revenues from proved reserves; plus the cost of
properties not being amortized, if any; plus the lower of cost or estimated fair
value of unproved properties included in the costs being amortized, if any; less
related income tax effects.
Proceeds from the sale of gas and oil properties are applied to reduce the
costs in the cost center unless the sale involves a significant quantity of
reserves in relation to the cost center, in which case a gain or loss is
recognized.
Unevaluated properties and associated costs not currently being amortized
and included in oil and gas properties were $159 million and $136 million at
January 31, 1997 and 1996, respectively. The properties represented by these
costs were undergoing exploration activities at such date, or are properties on
which the Company intends to commence such activities in the future. The Company
believes that the unevaluated properties at January 31, 1997 will be
substantially evaluated in 12 to 24 months and it will begin to amortize these
costs at such time.
Other Property and Equipment
Other property and equipment are stated at cost. The cost of repairs and
minor replacements is charged to operating expense while the cost of renewals
and betterments is capitalized. At the time depreciable assets are retired, or
otherwise disposed of, the cost and related accumulated depreciation or
amortization are removed from the accounts. Gains or losses on dispositions in
the ordinary course of business are included in the consolidated statement of
operations. Impairment of other property and equipment is reviewed whenever
events or changes in circumstances indicate that the carrying value of assets
may not be recoverable.
Depreciation of pipeline and transmission facilities, oilfield services
equipment and other buildings and equipment is computed by the straight-line
method at rates that will amortize the unrecovered cost of depreciable property,
including assets acquired under capital leases, over their estimated useful
lives.
Costs of improving leased property are amortized over the estimated useful
lives of the assets or the terms of the leases, whichever is shorter.
Environmental Remediation Costs
Environmental expenditures are expensed or capitalized as appropriate,
depending on their future economic benefit. Expenditures that relate to an
existing condition caused by past operations and that do not have future
economic benefits are expensed. Liabilities for these expenditures are provided
when the responsibility to remediate is probable and the amount of associated
costs is reasonably estimable.
Debt Issue Costs
Costs related to the issuance of long-term debt are classified as "Other
Assets." Capitalized debt costs are amortized to interest expense over the
scheduled maturity of the debt utilizing the straight-line method. In the
8
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
event of a redemption of long-term debt, the related debt issue costs will be
charged to income in the period of redemption.
Defined Contribution Plan
The Company, through its parent company, TransAmerican, maintains a defined
contribution plan, which incorporates a "401(k) feature" as allowed under the
Internal Revenue Code. All investments are made through Massachusetts Mutual
Life Insurance Company. Employees who are at least 21 years of age and have
completed one year of credited service are eligible to participate on the next
semiannual entry date. The Company matches 10%, 20% or 50% of employee
contributions up to a maximum of 3% of the participant's compensation, based on
years of plan participation. The Company and its predecessor's contributions
with respect to this plan totaled $0.5 million, $0.3 million, $0.2 million, $0.1
million, $0.3 million and $0.2 million for years ended January 31, 1997 and
1996, the six months ended January 31, 1996 and 1995 and the years ended July
31, 1995 and 1994, respectively. All Company contributions are currently funded.
Fair Value of Financial Instruments
The Company includes fair value information in the notes to consolidated
financial statements when the fair value of its financial instruments is
different from the book value. The Company believes the book value of those
financial instruments that are classified as current approximate fair value
because of the short maturity of these instruments. For noncurrent financial
instruments, the Company uses quoted market prices or, to the extent that there
are no available quoted market prices, market prices for similar instruments.
Revenue Recognition
The Company recognizes revenues from the sales of natural gas, condensate,
oil and natural gas liquids in the period of delivery. Revenues are recognized
from transportation of natural gas in the period the service is provided. The
sales method is used for natural gas imbalances that arise from jointly produced
properties.
Concentration of Credit Risk
Financial instruments that potentially expose the Company to credit risk
consist principally of cash, trade receivables and commodity price swap
agreements. TransTexas selects depository banks based upon management's review
of the financial stability of the institution. Balances periodically exceed the
$100,000 level covered by federal deposit insurance. To date, there have been no
losses incurred due to excess deposits in any financial institution. Trade
accounts receivable are generally from companies with significant natural gas
marketing activities, who would be impacted by conditions or occurrences
affecting that industry. For further information regarding the Company's hedging
arrangements, see Note 16. The Company performs ongoing credit evaluations and,
generally, requires no collateral from its customers.
Income Taxes
The Company files a consolidated tax return with TransAmerican. Income
taxes are due from or payable to TransAmerican in accordance with a tax
allocation agreement (the "Tax Allocation Agreement"). It is the Company's
policy to record income tax expense as though the Company had filed separately.
Pursuant to the Tax Allocation Agreement, the Company is able to recognize
currently any benefits related to available tight sands credits. Deferred income
taxes are recognized, at enacted tax rates, to reflect the future effects of tax
carryforwards and temporary differences arising between the tax bases of assets
and liabilities and their financial reporting amounts in accordance with
Statement of Financial Accounting Standards No. 109 and the Tax Allocation
Agreement between the Company, TransAmerican and TransAmerican's other
subsidiaries. Income taxes include federal and state income taxes.
9
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Recently Issued Pronouncements
In February 1997, the Financial Accounting Standards Board issued Statement
of Financial Accounting Standards No. 128, Earnings per Share ("SFAS 128") and
Statement of Financial Accounting Standards No. 129, Disclosure of Information
about Capital Structure ("SFAS 129"). These statements will be adopted by the
Company effective January 31, 1998. SFAS 128 simplifies the computation of
earnings per share by replacing primary and fully diluted presentations with the
new basic and diluted disclosures. SFAS 129 establishes standards for disclosing
information about an entity's capital structure. The Company has not determined
the impact of these pronouncements on its financial statements.
In October 1996, the American Institute of Certified Public Accountants
issued Statement of Position 96-1, Environmental Remediation Liabilities ("SOP
96-1"), which establishes new accounting and reporting standards for the
recognition and disclosure of environmental remediation liabilities. The Company
does not believe the effect of adoption of SOP 96-1 in 1998 will have a material
impact on the Company's financial position, results of operations or cash flows.
2. PUBLIC OFFERING
On June 20, 1995, the Company issued $800 million aggregate principal
amount of 11 1/2% Senior Secured Notes due 2002 (the "Notes"). The Notes are
senior obligations of the Company collateralized by a lien on substantially all
existing and future collateral of the Company, which initially includes
substantially all of the properties and assets of the Company other than
Equipment, Receivables and Inventory, as defined in the indenture governing the
Notes (the "Indenture"). Such lien is subject to subordination under certain
circumstances as provided in the Indenture governing the TransTexas Notes. The
Notes bear interest at the rate of 11 1/2% per annum, payable semiannually on
June 15 and December 15, commencing December 15, 1995. The Notes will mature on
June 15, 2002.
In connection with the offering of the Notes, the Company commenced a
tender offer to purchase for cash all of its $500 million principal amount of
Prior Notes for 105% of their principal amount plus accrued and unpaid interest
to the date of purchase. In addition, holders of the Prior Notes were offered a
consent fee equal to $30 per $1,000 principal amount of Prior Notes in return
for their consents to amendments to the indenture governing the Prior Notes.
Substantially all of the Prior Notes were tendered pursuant to this offer.
The Company received net proceeds of approximately $787 million from the
sale of the Notes after deducting underwriting discounts, fees and expenses. The
Company used approximately $556 million of the net proceeds to retire the entire
principal amount of the Prior Notes, including premium and consent fees and
accrued and unpaid interest, and approximately $46 million to establish an
interest reserve account. The remainder was used for lease acquisitions,
drilling and development and general and corporate purposes. The Company
recorded an extraordinary loss on the extinguishment of the Prior Notes of
approximately $56.6 million, net of an income tax benefit. The components of
this charge are as follows (in thousands of dollars):
Premium and consent fee..................................... $40,000
Write-off of unamortized debt issue costs................... 15,628
Underwriting fees and expenses.............................. 2,500
Related income tax benefit.................................. (1,491)
-------
$56,637
=======
10
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
3. OTHER CURRENT ASSETS
The major components of other current assets are as follows (in thousands
of dollars):
JANUARY 31,
------------------
1997 1996
------- -------
Prepayments:
Trade..................................................... $ 9,580 $ 4,464
Insurance................................................. 2,310 1,430
Properties held for sale.................................... -- 6,000
Deferred loss on commodity price swap agreements............ 8,276 31,317
Other....................................................... 4,818 7,610
------- -------
$24,984 $50,821
======= =======
4. PROPERTY AND EQUIPMENT
The major components of property and equipment, at cost, are as follows (in
thousands of dollars):
ESTIMATED JANUARY 31,
USEFUL LIFE ------------------------
(YEARS) 1997 1996
----------- ---------- ----------
Land............................................ $ 1,384 $ 660
Gas and oil properties.......................... 2,004,967 1,774,937
Gas transportation.............................. 10 193,443 160,819
Drilling services equipment and other........... 4-10 81,086 71,652
---------- ----------
$2,280,880 $2,008,068
========== ==========
On July 2, 1996, the Company consummated the sale, effective as of May 1,
1996, of producing properties in Zapata County, Texas for consideration of
approximately $62 million. On June 17, and August 13, 1996, the Company
consummated the sales, effective as of February 1, 1996, of certain other
producing properties in Webb County, Texas for consideration of approximately
$9.95 million and $21.5 million, respectively. The purchase price for each of
the properties discussed above was subject to adjustment for gas sales between
the effective date and the closing date. The Company retained the proceeds of
such gas sales.
In March 1996, the Company sold its 41.67% interest in the 76-mile, 24-inch
MidCon pipeline that runs from the Company's Thompsonville compressor station to
Agua Dulce for $7.5 million. The Company believes that its existing
transportation capacity in this area is adequate for the Company's production
and does not anticipate any material constraints on the transportation of its
natural gas as a result of this sale.
11
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
5. OTHER ASSETS
The major components of other assets are as follows (in thousands of
dollars):
JANUARY 31,
------------------
1997 1996
------- -------
Debt issue costs, net of accumulated amortization of $2,875,
and $1,788 at January 31, 1997 and 1996, respectively..... $14,645 $13,845
Litigation escrow........................................... -- 22,972
Other....................................................... 3,180 386
------- -------
$17,825 $37,203
======= =======
6. LONG-TERM DEBT
Long-term debt consists of the following (in thousands of dollars):
JANUARY 31,
--------------------
1997 1996
-------- --------
11 1/2% Senior Secured Notes due 2002....................... $800,000 $800,000
13 1/4% Senior Subordinated Notes due 2003.................. 101,092 --
Notes payable, ranging from 9.43% to 13.0%, due through
2001...................................................... 14,562 3,876
-------- --------
Total long-term debt...................................... 915,654 803,876
Less current maturities..................................... 5,787 1,335
-------- --------
$909,867 $802,541
======== ========
The Notes are senior obligations of the Company collateralized by a lien on
substantially all existing and future collateral of the Company, which initially
includes substantially all of the properties and assets of the Company other
than Equipment, Receivables and Inventory, as defined in the Indenture. The
Notes bear interest at the rate of 11 1/2% per annum, payable semiannually on
June 15 and December 15, commencing December 15, 1995. The Notes will mature on
June 15, 2002.
Capitalized words in the following discussion have the meanings as defined
in the Indenture. The Company will not have the right to redeem the Notes prior
to June 15, 2000, except that (i) prior to June 15, 1998, the Company may
redeem, at its option, up to $240 million aggregate principal amount of the
Notes in cash at a redemption price equal to 111.5% of the principal amount of
the Notes so redeemed, together with accrued and unpaid interest, if any, to the
redemption date, with the net proceeds of any Public Equity Offering and (ii) if
the Company makes a Major Asset Sale, the Company may redeem, at its option, at
any time after consummation of such Major Asset Sale, but in any event within 90
days of the expiration of any Offer to Purchase or any Change of Control Offer,
as applicable, made as a result of such Major Asset Sale, any or all of the
outstanding Notes in cash at a redemption price equal to 111.5% of the principal
amount of the Notes so redeemed, together with accrued and unpaid interest, if
any, to the redemption date. On or after June 15, 2000 and 2001, the Company
will have the right to redeem all or any part of the Notes in cash at the
redemption prices of 105.750% and 102.875%, respectively, together with accrued
and unpaid interest, if any, to the redemption date.
Pursuant to the Indenture, the Company maintains an account (the "Interest
Reserve Account") from which funds may only be disbursed in accordance with the
terms of a Cash Collateral and Disbursement Agreement (the "Disbursement
Agreement"). The Company deposited into the Interest Reserve Account, out of the
net proceeds from the sale of the Notes, funds sufficient to pay the aggregate
amount of the first interest payment due in respect of the Notes. Funds in the
Interest Reserve Account may be invested, at the direction of the Company
(except as provided below), only in cash and Cash Equivalents, and any interest
12
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
income thereon will be added to the balance of the Interest Reserve Account. The
Company must maintain a balance (the "Requisite Balance") in the Interest
Reserve Account at least equal to the amount necessary to satisfy the Company's
obligation to pay interest in respect of all then outstanding Notes on the next
Interest Payment Date; provided, however, that if, pursuant to the Disbursement
Agreement, any funds in the Interest Reserve Account are applied to the payment
of interest on the Notes, the Company shall not be obligated to maintain the
Requisite Balance during the period of 60 days immediately following the
Interest Payment Date in respect of which such payment was made.
The Company may instruct the disbursement agent under the Disbursement
Agreement to deposit with the Indenture Trustee, on any Interest Payment Date,
any or all of the funds in the Interest Reserve Account. The Disbursement
Agreement provides that if the Company fails to pay an installment of interest
on the Notes on any Interest Payment Date, then all investments in the Interest
Reserve Account will be immediately liquidated and all funds in the Interest
Reserve Account will be deposited with the Indenture Trustee. If the Company has
not paid such installment of interest within five days after such Interest
Payment Date, or if the Company so instructs the Indenture Trustee, the
Indenture Trustee will apply such deposited funds to the payment of interest on
the Notes. The Disbursement Agreement will provide that funds may be disbursed
from the Interest Reserve Account and released to the Company only to the extent
that the balance thereof exceeds the Requisite Balance.
If the Company's Working Capital, as of the end of any fiscal quarter, is
less than $20 million, then the Company's Capital Expenditures for the next
succeeding fiscal quarter may not exceed 90% of (a) the Company's Consolidated
EBITDA for such prior fiscal quarter minus (b) the Company's Consolidated Fixed
Charges for such prior fiscal quarter. The Indenture also contains other
covenants affecting the Company's liquidity and capital resources, including
restrictions on the Company's ability to incur indebtedness, pledge assets and
pay dividends on its common stock. Working Capital does not include current
assets or current liabilities of TTEX, an Unrestricted Subsidiary.
In December 1996, the Company issued $189 million in face amount of 13 1/4%
Series A Senior Subordinated Notes due 2003 ("Subordinated Notes") to
unaffiliated third parties. The Subordinated Notes were sold with original issue
discount at a price equal to 52.6166% of the principal amount shown on the face
thereof, for gross proceeds of approximately $99.45 million. The Subordinated
Notes accrete at a rate of 13 1/4% compounded semi-annually. At such time as the
Notes are rated "B1" or better by Moody's Investors Service, Inc. and "BB" or
better by Standard & Poor's Corporation, Inc., or when the Notes are paid in
full, the Subordinated Notes will be exchanged for notes bearing interest at a
rate of 13 1/4% per annum, payable semi-annually on December 31 and June 30. In
addition, the holders of the Subordinated Notes will have the right to exchange
their notes for notes to be registered under the Securities Act of 1933, as
amended. Proceeds from the issuance of the Subordinated Notes were used for
working capital and general corporate purposes.
The Company's notes payable bear interest at rates ranging from 9.43% to
13% per annum and mature at various dates through 2001. These notes payable are
collateralized by certain of the Company's operating equipment. Aggregate
principal payments on the Company's notes payable at January 31, 1997 total $5.2
million, $5.6 million and $0.7 million for the fiscal years ended January 31,
1998, 1999 and 2000, respectively.
The fair value of the Notes, based on quoted market prices, was
approximately $880 million and $818 million as of January 31, 1997 and 1996,
respectively. The fair value of the Subordinated Notes, based on quoted market
prices of similar instruments, was $104 million as of January 31, 1997.
Liquidity
A primary source of funds to meet the Company's debt service and capital
requirements is net cash flow provided by operating activities, which is
extremely sensitive to the prices the Company receives for its natural
13
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
gas. The Company has entered into hedge agreements to reduce its exposure to
price risk in the spot market for natural gas. However, a substantial portion of
the Company's production will remain subject to such price risk. Additionally,
significant capital expenditures are required for drilling and development,
lease acquisitions, pipeline and other equipment additions. Since July 31, 1995,
the Company has relied on asset sales and various financings, in addition to
cash flow from operating activities, to meet its working capital requirements,
including maintenance of Working Capital as defined in the Indenture. The
Company anticipates that it will require additional financing or sales of assets
to fund planned levels of operations through at least January 1998.
The Company is engaged in exclusive negotiations to sell all of the stock
of TTC, its subsidiary that owns substantially all of the Company's Lobo Trend
producing properties and related pipeline transmission system, for an estimated
sales price of approximately $1.1 billion. In addition, the Company has engaged
an investment banking firm to assist in the sale of its interest in the
Lodgepole prospect in North Dakota. The Company intends to use the proceeds from
these transactions for general corporate purposes, which may include a
recapitalization of TransTexas. There can be no assurance that the Lobo Sale
will be consummated or, if consummated, will be upon the terms described herein.
7. SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
The following information reflects the Company's noncash investing and
financing activities (in thousands of dollars):
YEAR ENDED SIX MONTHS ENDED
JANUARY 31, JANUARY 31, YEAR ENDED JULY 31,
--------------------- --------------------- -------------------
1997 1996 1996 1995 1995 1994
------- ----------- ------- ----------- -------- --------
(UNAUDITED) (UNAUDITED)
Seller financed obligations
incurred for capital
expenditures.............. $ 3,621 $ 1,095 $ 1,095 $ -- $ -- $ --
======= ======= ======= ======= ======= =======
Accounts payable and
long-term liabilities for
property and equipment.... $27,192 $29,191 $29,191 $ -- $ -- $ --
======= ======= ======= ======= ======= =======
Cash paid for interest and income taxes are as follows (in thousands of
dollars):
YEAR ENDED SIX MONTHS ENDED
JANUARY 31, JANUARY 31, YEAR ENDED JULY 31,
--------------------- --------------------- -------------------
1997 1996 1996 1995 1995 1994
------- ----------- ------- ----------- -------- --------
(UNAUDITED) (UNAUDITED)
Interest.................... $85,254 $88,468 $41,052 $29,971 $75,863 $26,978
======= ======= ======= ======= ======= =======
Income taxes (paid to
TransAmerican)............ $ 7,000 $ -- $ -- $ -- $ -- $ 1,858
======= ======= ======= ======= ======= =======
The Company incurred approximately $112.9 million, $90.2 million, $50.8
million and $69.4 million of interest charges of which approximately $15.9
million, $8.3 million, $7.4 million and $0.9 million was capitalized for the
years ended January 31, 1997 and 1996, the six months ended January 31, 1996 and
the year ended July 31, 1995, respectively, in connection with the acquisition
of certain of the Company's unevaluated gas and oil properties. During 1994, the
Company capitalized a total of approximately $0.7 million of interest in
connection with the expansion of the Company's pipeline system.
14
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
8. ACCRUED LIABILITIES
The major components of accrued liabilities are as follows (in thousands of
dollars):
JANUARY 31,
------------------
1997 1996
------- -------
Royalties................................................... $27,607 $ 9,793
Taxes other than income taxes............................... 10,136 2,733
Accrued interest............................................ 13,370 11,756
Payroll..................................................... 5,413 4,832
Litigation settlements...................................... 1,263 7,053
Settlement values of commodity price swap agreements........ 13,276 31,317
Insurance................................................... 6,618 1,248
Other....................................................... 5,728 6,024
------- -------
$83,411 $74,756
======= =======
9. OTHER LIABILITIES
The major components of other liabilities are as follows (in thousands of
dollars):
JANUARY 31,
------------------
1997 1996
------- -------
Litigation accrual.......................................... $ 8,008 $12,171
Litigation settlements...................................... 1,633 --
Short-term obligations expected to be refinanced:
Litigation settlements.................................... 2,500 14,747
Accrued capital expenditures.............................. 19,738 5,443
Current portion of dollar-denominated production
payments............................................... -- 1,765
Other....................................................... 1,112 1,064
------- -------
$32,991 $35,190
======= =======
In April 1997, the Company sold to an unaffiliated third party a term
royalty in the form of a dollar-denominated production payment in certain of the
Company's properties for net proceeds of approximately $20 million. The Company
also completed a financing in the amount of $8.3 million at an interest rate of
12.7% per annum and a 36-month term, collateralized by certain operating
equipment. Proceeds from these transactions, net of current maturities, were
used to pay all of the obligations listed above under the caption "Short-term
obligations expected to be refinanced" at January 31, 1997.
In February 1996, the Company completed a financing in the amount of $10
million at an interest rate of 12% per annum and a 36-month term, collateralized
by certain operating equipment. In February 1996, the Company also amended a
purchase agreement with an unaffiliated third party related to a volumetric
production payment to include an additional 14 Bcf which were sold to the third
party for a purchase price of approximately $16 million. Proceeds from these
transactions net of current maturities were used to pay all of the obligations
listed above under the caption "Short-term obligations expected to be
refinanced" at January 31, 1996.
15
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
10. INCOME TAXES
Income tax expense (benefit) includes the following (in thousands of
dollars):
YEAR ENDED SIX MONTHS ENDED
JANUARY 31, JANUARY 31, YEAR ENDED JULY 31,
---------------------- ------------------- -------------------
1997 1996 1996 1995 1995 1994
-------- ----------- ----- ----------- -------- --------
(UNAUDITED) (UNAUDITED)
Federal:
Current.................... $ 21,380 $(8,963) $ -- $ 1,352 $(7,611) $10,909
Deferred................... (8,889) 6,263 (416) (1,483) 5,196 (5,961)
State:
Current.................... -- -- -- -- -- 432
-------- ------- ----- ------- ------- -------
Income tax expense (benefit)
before extraordinary
item....................... 12,491 (2,700) (416) (131) (2,415) 5,380
Tax benefit of extraordinary
item....................... -- (1,491) -- -- (1,491) --
-------- ------- ----- ------- ------- -------
Total income tax expense
(benefit).................. $ 12,491 $(4,191) $(416) $ (131) $(3,906) $ 5,380
======== ======= ===== ======= ======= =======
In August 1993, the Omnibus Reconciliation Act of 1993, among other things,
increased the maximum corporate marginal federal income tax rate to 35% from 34%
effective January 1, 1993. Deferred income taxes as of July 31, 1994 include an
adjustment of approximately $2.7 million related to this increase in corporate
tax rates. Included in "Payable to affiliates" at January 31, 1997 and 1996 are
income taxes payable to TransAmerican totaling approximately $14.4 million and
$3.0 million, respectively.
During the third quarter of 1994, TransAmerican's refining subsidiary
reached a level of operations, which, for federal income tax purposes, changed
the tax status of TransAmerican's consolidated group to an integrated oil
company from an independent producer. As a result of this change in tax status,
the Company was able to utilize a greater portion of its available tight sands
credits, thereby reducing its effective tax rate for 1994. The Company was
unable to utilize any tight sands credits during the Transition Period or in
1995 due to its net loss position. Total income tax expense differs from amounts
computed by applying the statutory federal income tax rate to income before
income taxes. The items accounting for this difference are as follows (in
thousands of dollars):
YEAR ENDED SIX MONTHS ENDED
JANUARY 31, JANUARY 31, YEAR ENDED JULY 31,
--------------------- ------------------- --------------------
1997 1996 1996 1995 1995 1994
------- ----------- ----- ----------- --------- --------
(UNAUDITED) (UNAUDITED)
Federal income tax expense
(benefit) at the statutory
rate....................... $33,536 $(25,637) $(416) $(131) $(25,352) $10,197
Increase (decrease) in tax
resulting from:
Tax rate change............ -- -- -- -- -- 2,745
State income taxes, net of
Federal income tax
benefit................. -- -- -- -- -- 281
Tight sands credit......... (7,441) 7,842 -- -- 7,842 (7,843)
Valuation allowance........ (13,604) 13,604 -- -- 13,604 --
------- -------- ----- ----- -------- -------
$12,491 $ (4,191) $(416) $(131) $ (3,906) $ 5,380
======= ======== ===== ===== ======== =======
16
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Significant components of the Company's tax attributes are as follows (in
thousand of dollars):
JANUARY 31,
---------------------
1997 1996
--------- --------
Deferred tax liabilities:
Depreciation, depletion and amortization.................. $ 82,274 $ 83,724
Other, net................................................ 1,139 359
--------- --------
83,413 84,083
--------- --------
Deferred tax assets:
Investment in affiliates.................................. 275,450 --
Net operating loss carryforwards.......................... -- 22,687
Contingent liabilities.................................... 3,403 3,700
Alternative minimum tax credit carryforward............... 48,643 31,044
--------- --------
327,496 57,431
Valuation allowance......................................... (275,450) (13,604)
--------- --------
Net deferred tax assets..................................... 52,046 43,827
--------- --------
$ 31,367 $ 40,256
========= ========
The Company can only use alternative minimum tax credit carryforwards to
the extent it is a regular federal income tax payer.
In order to realize the deferred tax asset related to the investment in
affiliate, TransTexas must sell the common stock of the affiliate and generate
sufficient taxable income to offset the asset amount. A valuation allowance has
been provided for this deferred tax asset as it is not more likely than not that
the aforementioned events will occur.
Under certain circumstances, TransAmerican, TransAmerican Exploration
Corporation ("TEXC"), TEC or TARC may sell or otherwise dispose of shares of
common stock of the Company. If, as a result of any sale or other disposition of
the Company's common stock, the direct and indirect ownership of the Company by
TransAmerican is less than 80% (measured by voting power and value), the Company
will no longer be a member of TransAmerican's consolidated group for federal tax
purposes (the "TNGC Consolidated Group") and, with certain exceptions, will no
longer be obligated under the terms and conditions of, or entitled to the
benefits of, the Tax Allocation Agreement ("Deconsolidation"). Such sales may be
necessary to raise funds required to complete TARC's Capital Improvement
Program. Further, if TEC or TARC sells or otherwise transfers any stock of TARC,
or issues any options, warrants or other similar rights relating to such stock,
outside of the TNGC Consolidated Group, then a Deconsolidation of both TARC and
the Company from the TNGC Consolidated Group would occur. An event that results
in Deconsolidation of the Company from the TNGC Consolidated Group for tax
purposes could result in the acceleration of payment of a substantial amount of
federal income taxes by TransAmerican. The tax liability to TransAmerican that
would result from Deconsolidation is estimated to be approximately $15 million
at January 31, 1997. Each member of a consolidated group filing a consolidated
federal income tax return is severally liable for the consolidated federal
income tax liability of the consolidated group. There can be no assurance that
TransAmerican will have the ability to satisfy the above tax obligation at the
time due and, therefore, the Company, TARC or TEC may be required to pay the
tax.
Under the Tax Allocation Agreement, the Company will be required to pay any
Texas franchise tax (which is estimated not to exceed $10.6 million) which may
be attributable to any gain recognized by TransAmerican on the Transfer and will
be entitled to any benefits of the additional basis resulting from the
recognition of such gain.
17
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
11. TRANSACTIONS WITH AFFILIATES
In February 1996, the Company purchased the building for its corporate
headquarters from TransAmerican for $4 million.
In December 1994, the Company entered into an interruptible gas sales
agreement with TransAmerican, revenues from which totaled approximately $11.7
million, $21.4 million, $11.1 million, $4.4 million and $14.8 million for the
years ended January 31, 1997 and 1996, the six months ended January 31, 1996 and
1995 and the year ended July 31, 1995, respectively. The receivable from
TransAmerican for natural gas sales totaled approximately $13.6 million at
January 31, 1997. Pursuant to this agreement, interest accrues on all unpaid
balances at a rate of prime plus 2% per annum.
The Company sells natural gas to TARC under an interruptible long-term
sales contract. Revenues from TARC under this contract totaled approximately
$2.7 million and $2.4 million, respectively, for the years ended January 31,
1997 and 1996, $2.2 million and $2.3 million, respectively, for the six months
ended January 31, 1996 and 1995 and $2.5 million and $2.3 million, respectively,
for the years ended July 31, 1995 and 1994. The receivable from TARC for natural
gas sales totaled approximately $3.2 million at January 31, 1997.
As of January 1996, the Company and TTEX entered into a Drilling Program,
as defined in the Indenture. Pursuant to the Program, TTEX received a portion of
revenues, in the form of a production payment, from certain of the Company's
wells. The production payment was transferred in consideration of a note payable
in the amount of $23.7 million issued by TTEX. In July 1996, TTEX transferred
this production payment to the Company in the form of a dividend, and the
Company forgave the $13.2 million remaining balance of the note payable.
In July 1996, TTEX loaned $9.5 million to TransAmerican pursuant to the
terms of a $25 million promissory note due July 31, 1998 that bears interest,
payable quarterly, at 15% per annum. TTEX has made further advances pursuant to
the note, subject to the same terms. The amount outstanding under this
promissory note totaled approximately $26.6 million at January 31, 1997. The
Company believes that the advances by TTEX to TransAmerican reduce the risk of
tax deconsolidation (and potential tax liability of the Company) that could be
caused by the sale of shares of the Company's common stock by TransAmerican or
its affiliates. TransAmerican has not made its scheduled interest payments on
this note. TTEX has agreed to defer the interest payments on the note until
1998.
Pursuant to the terms of the Transfer Agreement, TransAmerican is obligated
to indemnify the Company for all future losses incurred in connection with
litigation or bankruptcy claims assumed in the Transfer. In order to facilitate
the settlement of the Terry/Penrod litigation in May 1996, the Company advanced
to TransAmerican $16.4 million of the settlement amount in exchange for a note
receivable. TransAmerican has not made its scheduled interest payments on this
note. The Company has agreed to defer the interest payments on the note until
1998. In addition, the Company transferred escrowed funds of approximately $22
million to TransAmerican pursuant to the Terry/Penrod settlement. In connection
with this settlement, the Company received from Terry the reversionary interest
in certain producing properties. The Company and TransAmerican had intended that
such interests would revert to TransAmerican under the Transfer Agreement;
however, the Company retained such interests in partial satisfaction of
TransAmerican's indemnity obligations. The amount outstanding under this
agreement totaled approximately $7 million at January 31, 1997.
In September 1996, the Company purchased from TransDakota Oil Corporation
("TDOC"), a subsidiary of TransAmerican, certain oil and gas leasehold interests
located in the Lodgepole area in North Dakota for approximately $20 million. The
Company believes that the combination of these interests, together with the
Company's other interests in the Lodgepole area, will produce a more marketable
property package. The purchase price was $3.9 million greater than TDOC's basis
in the properties. The properties have been
18
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
recorded in the Company's financial statements at carryover basis and the $3.9
million has been classified as a reduction of retained earnings.
The Company provides accounting and legal services to TARC and TEC and
drilling and workover, administrative and procurement, accounting, legal, lease
operating, and gas marketing services to TransAmerican pursuant to a services
agreement (the "Services Agreement"). The Company provides general commercial
legal services and certain accounting services (including payroll, tax, and
treasury services) to TARC and TEC for a fee of $26,000 per month. At
TransAmerican's request, the Company, at its election, may provide drilling and
workover services. The receivable under this agreement was approximately $5.1
million as of January 31, 1997.
The Company has made various advances in an aggregate of approximately $7
million for lease purchases and other corporate expenses. The entire amount was
outstanding at January 31, 1997.
In September 1996, the Company and TransAmerican entered into an agreement
pursuant to which the Company obtained an $11.5 million dollar-denominated
production payment, subsequently increased to $19 million, bearing interest at
17% per annum, burdening certain oil and gas interests owned by TransAmerican as
a source of repayment for certain of the receivables from TransAmerican
discussed above. On January 31, 1997, TransAmerican conveyed at historical cost
certain oil and gas properties to the Company for a purchase price of $31.6
million. A portion of the purchase price was used to offset obligations under
the September 1996 production payment. At January 31, 1997, $59 million of
related-party receivables has been recorded as a contra-stockholder equity
account due to uncertainties regarding the repayment terms for such receivables.
The Company has agreed to defer any interest payments due from TransAmerican
until 1998.
In January 1997, an affiliate of the Company contributed all of the
outstanding common stock of Signal Capital Holdings Corporation ("SCHC"), with a
book value of $6 million, to TransTexas. In the same month, TransTexas
contributed the stock of SCHC to TransTexas Transmission Corporation ("TTC").
In January 1997, TransTexas contributed substantially all of its Lobo Trend
properties to TTC (see Note 13).
12. COMMITMENTS AND CONTINGENCIES
Legal Proceedings
As part of the Transfer, the Company has succeeded to the potential
liability, if any, of TransAmerican and certain subsidiaries in connection with
the lawsuits described below. The Company has assumed liability for litigation
up to $15 million plus the difference, if any, between $10 million and the costs
(if less than $10 million) incurred to resolve the disputed claims. Pursuant to
an agreement among the Company, TransAmerican and certain of its subsidiaries,
as amended (the "Transfer Agreement"), TransAmerican has agreed to indemnify the
Company against all losses incurred by the Company in excess of $25 million in
connection with (a) disputed claims in TransAmerican's bankruptcy and (b) other
litigation assumed by the Company and other agreements related to
TransAmerican's plan of reorganization (other than settlements and judgments
paid from escrowed cash established in connection with TransAmerican's plan of
reorganization). TransAmerican is required to indemnify the Company for all
future losses incurred in connection with litigation or bankruptcy claims
assumed in the Transfer. Any indemnification payments received from
TransAmerican for which the Company is the primary obligor will be considered a
contribution of capital. There can be no assurance that TransAmerican will have
the financial ability to meet its indemnification obligations.
Alameda. On May 22, 1993, Alameda Corporation ("Alameda") sued
TransAmerican and John R. Stanley in the 234th Judicial District Court, Harris
County, Texas, claiming that TransAmerican failed to account to Alameda for a
share of the proceeds TransAmerican received in a 1990 settlement of litigation
with
19
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
El Paso Natural Gas Company ("El Paso"), and that TransAmerican has been
unjustly enriched by its failure to share such proceeds with Alameda. The court
granted Mr. Stanley's motion for summary judgment. On September 20, 1995, the
jury rendered a verdict in favor of TransAmerican. Alameda appealed to the
Fourteenth Court of Appeals, which affirmed the trial court judgment in favor of
TransAmerican. Alameda filed a motion for rehearing on April 10, 1997.
Coastal. On October 28, 1991, The Coastal Corporation ("Coastal") filed an
action against TransAmerican that was consolidated in the 49th Judicial District
Court, Webb County, Texas, alleging breach of contract and tortious interference
related to two gas sales contracts and a transportation agreement, seeking
unspecified actual and punitive damages and injunctive relief. On April 22,
1994, the court entered a judgment adverse to TransAmerican and the Company
requiring them to pay $1.3 million plus $0.7 million in attorneys' fees to
Coastal. On May 29, 1996, the Court of Appeals affirmed the judgment. In
December 1996, the Supreme Court of Texas declined to hear the appeal. Pursuant
to the final judgment, TransTexas is required to remit the judgment amount plus
interest on or before May 25, 1997 or Coastal will have a right of offset for
gas delivered pursuant to a contract with TransTexas.
Aspen. TransAmerican brought suit on September 29, 1993 against Aspen
Services, Inc. ("Aspen"), seeking an audit and accounting of drilling costs that
Aspen had charged while providing drilling services to TransAmerican. This suit
is pending in the 215th Judicial District Court, Harris County, Texas. The
parties' drilling agreement provided, among other things, that Aspen would
receive payment for its drilling-related costs from the production and sale of
gas from the wells that were drilled, and that the revenues that TransAmerican
would otherwise receive from the wells would be reduced by the amounts received
by Aspen. On July 19, 1995, Aspen filed a counterclaim and third party claim
against TransAmerican, the Company, and affiliated entities, asserting, among
other things, that these entities failed to make certain payments and properly
market the gas from these wells. Aspen is seeking damages in an unspecified
amount, as well as certain equitable claims. In April 1997, the trial court
ruled against Aspen on all of its claims and counterclaims.
Finkelstein. On April 15, 1990, H.S. Finkelstein filed suit against
TransAmerican in the 49th Judicial District Court, Zapata County, Texas,
alleging that TransAmerican failed to pay royalties and improperly marketed oil
and gas produced from certain leases. On September 27, 1994, the plaintiff added
the Company as an additional defendant. On January 6, 1995, a judgment against
TransAmerican and the Company was entered for approximately $18 million in
damages, interest and attorneys' fees. The Company and TransAmerican appealed
the judgment to the Fourth Court of Appeals, San Antonio, Texas, which affirmed
the judgment on April 3, 1996. The Company and TransAmerican filed a motion for
rehearing. On August 14, 1996, the Fourth Court of Appeals reversed the trial
court judgment and rendered judgment in favor of TransAmerican and the Company.
On August 29, 1996, the plaintiff filed a motion for stay and a motion for
rehearing with the court. On October 9, 1996, the court denied Finkelstein's
rehearing request. In November 1996, Finkelstein filed an application for writ
of error with the Supreme Court of Texas.
On April 22, 1991, the plaintiff filed a separate suit against
TransAmerican and various affiliates in the 49th Judicial District Court, Zapata
County, Texas, alleging an improper calculation of overriding royalties
allegedly owed to the plaintiff and seeking damages and attorneys' fees in
excess of $33.7 million. On November 18, 1993, the plaintiff added the Company
as an additional defendant. The parties arbitrated this matter in January 1997.
A decision is expected in May 1997.
Briones. In an arbitration proceeding, Jesus Briones, a lessor, claimed
that one of the Company's wells on adjacent lands had been draining natural gas
from a portion of his acreage leased to the Company on which no well had been
drilled. On October 31, 1995, the Arbitrator decided that drainage had occurred.
On June 3, 1996, the Arbitrator issued a letter indicating that drainage damages
would be awarded to Briones in the amount of approximately $1.4 million. The
Arbitrator entered his award of damages on June 27, 1996. On July 3, 1996, the
Company filed a petition in the 49th Judicial District Court, Zapata County,
Texas, to vacate
20
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
the Arbitrator's award. Briones also filed its petition to confirm the
Arbitrator's award. In March 1997, the court determined to grant Briones' motion
for summary judgment. TransTexas intends to file a motion for a new trial.
Frost. On November 10, 1994, Frost National Bank filed suit against the
Company in the 111th Judicial District Court, Webb County, Texas, seeking a
declaratory judgment determination that the Company failed to properly and
accurately calculate royalties under a lease. The plaintiff has demanded $10
million plus interest. This litigation is in the discovery stage and trial is
set for September 8, 1997.
Farias. On February 15, 1996, Celita Suzana Farias filed a wrongful death
action in the 93rd Judicial District Court, Hidalgo County, Texas, against the
Company and one of its contractors for fatal injuries suffered by the
plaintiff's husband at the Yzaguirre Heirs #3 Well on February 13, 1996. The
plaintiff alleges the defendants operated a crane in such a manner that they
were negligent and grossly negligent. The plaintiff seeks unspecified damages.
On March 7, 1996, the mother of the deceased Company employee filed a petition
in intervention also alleging negligence, gross negligence and malice and
seeking unspecified damages. This litigation is in the discovery stage.
The Company is also a named defendant in other ordinary course, routine
litigation incidental to its business. Although the outcome of these other
lawsuits cannot be predicted with certainty, the Company does not expect these
matters to have a material adverse effect on its financial position. At January
31, 1997, the possible range of estimated losses related to all of the
aforementioned claims, in addition to the estimates accrued by the Company, is
$0 to $36 million. The resolution in any reporting period of one or more of
these matters in a manner adverse to the Company could have a material impact on
the Company's results of operations and cash flows for that period. Litigation
expense, including legal fees, was approximately $19 million and $11 million for
the years ended January 31, 1997 and 1996, respectively. Litigation expense,
consisting primarily of legal fees, totaled approximately $3 million and $2
million, respectively, for the six months ended January 31, 1996 and 1995.
Litigation expense, including legal fees, was approximately $11 million and $20
million for the years ended July 31, 1995 and 1994, respectively. The Company
has delivered letters of credit and placed into escrow cash, which letters of
credit and cash total approximately $21 million, to be applied to the litigation
claims described above.
Environmental Matters
The Company's operations and properties are subject to extensive federal,
state, and local laws and regulations relating to the generation, storage,
handling, emission, transportation, and discharge of materials into the
environment. Permits are required for various of the Company's operations, and
these permits are subject to revocation, modification, and renewal by issuing
authorities. The Company also is subject to federal, state, and local laws and
regulations that impose liability for the cleanup or remediation of property
which has been contaminated by the discharge or release of hazardous materials
or wastes into the environment. Governmental authorities have the power to
enforce compliance with their regulations, and violations are subject to fines
or injunctions, or both. It is not anticipated that the Company will be required
in the near future to expend amounts that are material to the financial
condition or operations of the Company by reason of environmental laws and
regulations, but because such laws and regulations are frequently changed and,
as a result, may impose increasingly strict requirements, the Company is unable
to predict the ultimate cost of complying with such laws and regulations.
Potential Effects of a Change of Control
The Indenture provides that, upon the occurrence of a Change of Control (as
such term is defined in the Indenture), each holder of the Notes will have the
right to require the Company to repurchase such holder's Notes at 101% of the
principal amount thereof plus accrued and unpaid interest. A Change of Control
would be deemed to occur under the Indenture in the case of certain changes or
other events in respect of the
21
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
ownership or control of the Company, including any circumstance pursuant to
which any person or group, other than John R. Stanley and his wholly-owned
subsidiaries or the trustee under the indenture governing TARC's $440 million
aggregate principal amount of mortgage notes ("TARC Notes") is or becomes the
beneficial owner of more than 50% of the total voting power of the Company's
then outstanding voting stock, unless the Notes have an investment grade rating
for the period of 120 days thereafter. The term "person," as used in the
definition of Change of Control, means a natural person, company, government or
political subdivision, agency or instrumentality of a government and also
includes a "group," which is defined as two or more persons acting as a
partnership, limited partnership or other group. The holders of the Subordinated
Notes would also have a right to require the Company to repurchase such
securities upon the occurrence of a change of control. In addition, certain
changes or other events in respect of the ownership or control of the Company
that do not constitute a Change of Control under the Indenture may result in a
"change of control" of the Company under the terms of the Company's credit
facility (the "BNY Facility") and certain equipment financing. Such an
occurrence could create an obligation for the Company to repay such other
indebtedness. At January 31, 1997, the Company had approximately $34.7 million
of indebtedness (excluding the Notes and Subordinated Notes) subject to such
right of repayment or repurchase. In the event of a Change of Control under the
Indenture or a "change of control" under the terms of other outstanding
indebtedness, there can be no assurance that the Company will have sufficient
funds to satisfy any such payment obligations.
TARC owns a large petroleum refinery in the Gulf Coast region along the
Mississippi River, approximately 20 miles from New Orleans, Louisiana. In
February 1995, TARC began a construction and expansion program designed to
reactivate the refinery and increase its complexity ("Capital Improvement
Program"). TARC's debt securities are collateralized by, among other things, an
aggregate of 50.45 million shares of the Company's common stock (the "Common
Stock"). From February 1995 through March 1997, TARC spent approximately $238
million on the Capital Improvement Program, procured a majority of the equipment
required and completed substantially all of the process design engineering and a
substantial portion of the remaining engineering necessary to complete this
project.
Primarily because additional funding was not available to TARC on a timely
basis, TARC was unable to meet the construction completion timetable for the
Capital Improvement Program as required under the TARC Notes Indenture. The
Holders of the TARC Notes have waived, until July 15, 1997, the default under
the TARC Notes Indenture which would have occurred on February 15, 1997 as a
result of TARC's failure to meet the required completion timetable. The waiver
of this default will cease to be effective on July 15, 1997. Unless the default
has been further waived or TARC completes a recapitalization that satisfies the
holders of the TARC Notes, such holders would then be entitled to pursue
remedies available under the TARC Notes Indenture, including acceleration of the
maturity of the TARC Notes. Any such event of default could result in the sale,
following the occurrence of such event of default, of some or all of the
remaining shares of Common Stock pledged to collateralize the TARC Notes. A
foreclosure on such shares would constitute a "change of control" of the Company
under the BNY Facility and certain equipment financing, which may create an
obligation for the Company to repay amounts outstanding thereunder. A sale of
such shares following a foreclosure could also result in a Change of Control
under the Indenture.
22
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Operating Leases
As of January 31, 1997, the Company has long-term leases covering land and
other property and equipment. Rental expense was approximately $6 million and $4
million for the twelve months ended January 31, 1997 and 1996, respectively, $3
million for each of the six months ended January 31, 1996 and 1995 and $5
million and $4 million for the fiscal years ended July 31, 1995 and 1994,
respectively. Future minimum rental payments required under operating leases
that have initial or remaining noncancellable lease terms in excess of one year
as of January 31, 1997, including the sale-leaseback transaction described
below, are as follows (in thousands of dollars):
1998...................................................... $2,896
1999...................................................... 1,900
2000...................................................... 1,791
2001...................................................... 1,450
2002...................................................... 926
------
$8,963
======
In January 1996, the Company completed a sale-leaseback transaction in the
amount of $3 million, related to its operating equipment. The sale-leaseback
transaction has a monthly lease payment of approximately $56,000 per month and a
60-month term. At the end of the lease term, the lease will automatically renew
for 12 months at approximately $38,000 per month.
Gas Sales Commitments
In February 1990, TransAmerican amended a long-term gas sales contract,
whereby TransAmerican potentially increased the price to be received for future
sales under the amended contract. In consideration, TransAmerican agreed to pay
the buyer approximately $0.4 million per month through June 1997. This
commitment was assumed by the Company.
The Company and PanEnergy Trading and Market Service, Inc. entered into a
long-term firm gas purchase contract on August 31, 1994 under which the Company
will deliver 100,000 MMBtu of natural gas per day through August 1997. The
selling price for this gas is determined by certain industry averages as defined
in the contract.
The Company and MidCon entered into a long-term gas purchase contract on
January 10, 1996, under which the Company is required to deliver a total of
100,000 MMBtu per day to four specified delivery points for a period of five
years. The purchase price is determined by an industry index less $0.09 per
MMBtu. Deliveries commenced September 1, 1996.
Letter of Credit
In January 1996, the Company entered into a reimbursement agreement with an
unaffiliated third party pursuant to which the third party caused a $20 million
letter of credit to be issued to collateralize a supersedeas bond on behalf of
the Company. If there is a draw under the letter of credit, the Company is
required to reimburse the third party within 60 days. The Company has agreed to
issue up to 8.6 million shares of common stock of the Company to the third party
if this contingent obligation to such third party becomes fixed and remains
unpaid for 60 days. The Company does not believe that this contingency will
occur. If the obligation becomes fixed, and alternative sources of capital are
not available, the Company could elect to sell shares of the Company's common
stock prior to the maturity of the obligation and use the proceeds of such sale
to repay the third party. Based on the current capitalization of the Company,
the issuance of shares to satisfy this obligation would result in
Deconsolidation for tax purposes (see Note 10).
23
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Production Payments
On February 28, 1995, the Company sold to an unaffiliated third party a
term royalty in the form of a dollar-denominated production payment in certain
of the Company's properties for proceeds of $49.5 million, less closing costs of
approximately $2 million. This production payment was paid in full in May 1996
with a portion of the proceeds of the volumetric production payment described
below.
In January 1996, the Company sold to an unaffiliated third party a term
overriding royalty interest in the form of a volumetric production payment
carved out of its interests in certain of its producing properties. For net
proceeds of approximately $33 million, the Company conveyed to the third party a
term overriding royalty equivalent to a base volume of approximately 29 Bcf of
natural gas, subject to certain increases in the base volume and in the
percentage interest dedicated if certain minimum performance and delivery
requirements are not met. In February 1996, in consideration for additional net
proceeds of approximately $16 million, the Company supplemented the production
payment to subject a percentage of its interests in certain additional producing
properties to the production payment and to include additional volumes of
approximately 14 Bcf of natural gas within the base volume subject to the
production payment. At January 31, 1997, approximately 23 Bcf of natural gas
remained subject to this production payment.
In May 1996, the Company sold to two unaffiliated third parties a
volumetric production payment for net proceeds of approximately $43 million. The
Company conveyed to the third parties a term overriding royalty equivalent to a
base volume of approximately 37 Bcf of natural gas, subject to certain increases
in the base volume and in the percentage interest dedicated if certain minimum
performance and delivery requirements are not met. Concurrently with the closing
of that transaction, the Company and one of the unaffiliated third parties
terminated, prior to the expiration of its stated term, a dollar-denominated
term overriding royalty interest previously sold by the Company to that
unaffiliated third party for a payment by the Company of approximately $25
million. At January 31, 1997, approximately 24 Bcf of natural gas remained
subject to this production payment.
In September 1996, the Company sold to an unaffiliated third party a term
royalty in the form of a dollar-denominated production payment in certain of the
Company's properties for proceeds of $13.5 million. The production payment calls
for the repayment of the primary sum plus an amount equivalent to a 16% annual
interest rate on the unpaid portion of such primary sum.
In September 1996, the Company entered into a drilling program agreement
with an unaffiliated third party for the reimbursement of certain drilling costs
with respect to wells drilled by the Company. Pursuant to the agreement, upon
the approval of the third party of a recently drilled or currently drilling well
for inclusion in the program, the third party will commit to the reimbursement
of all or a portion of the cost of such well, up to an aggregate maximum for all
such wells of $16.5 million. The program wells are subject to a dollar-
denominated production payment equal to the primary sum of such reimbursed
costs, plus an amount equivalent to a 17.5% annual interest rate on the unpaid
portion of such primary sum.
In April 1997, the Company sold to an unaffiliated third party a term
royalty in the form of a dollar-denominated production payment in certain of the
Company's properties for proceeds of approximately $20 million. The production
payment calls for the repayment of the primary sum plus an amount equivalent to
a 16% annual interest rate on the unpaid portion of such primary sum.
Possible Federal Tax Liability
Part of the refinancing of TransAmerican's debt in 1993 involved the
cancellation of approximately $65.9 million of accrued interest and of a
contingent liability for interest of $102 million owed by TransAmerican. No
federal tax opinion was rendered with respect to this transaction, however, and
TransAmerican has not obtained a ruling from the Internal Revenue Service (the
"IRS") regarding this transaction. TransAmerican has taken the federal tax
position that the entire amount of this debt cancellation
24
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
is excluded from its income under the cancellation of indebtedness provisions
("COD Exclusion") of the Internal Revenue Code of 1986, as amended (the "Code"),
and has reduced its tax attributes (including its net operating loss and credit
carryforwards) as a consequence of the COD Exclusion. TransTexas believes that
there is substantial legal authority to support the position that the COD
Exclusion applies to the cancellation of TransAmerican's indebtedness. However,
due to factual and legal uncertainties there can be no assurance that the IRS
will not challenge this position, or that any such challenge would not be
upheld. Under the Tax Allocation Agreement, the Company has agreed to pay an
amount equal to any federal tax liability (which would be approximately $25.4
million) attributable to the inapplicability of the COD Exclusion. Any such tax
would be offset in future years by alternative minimum tax credits and retained
loss and credit carryforwards to the extent recoverable from TransAmerican. The
IRS has commenced an audit of the TransAmerican Consolidated Group's tax returns
for its taxable years ended July 31, 1994 and July 31, 1995. Because the audit
is in its initial stages, it is not possible to predict the scope of the IRS'
review or whether any tax deficiencies will be proposed by the IRS as a result
of its review.
The Company has significant contingent liabilities, including liabilities
with respect to litigation matters and other obligations assumed in the
Transfer. In addition, a change of control or other event that results in
deconsolidation of the Company and TransAmerican for federal income tax purposes
could result in acceleration of a substantial amount of federal income taxes.
These matters, individually and in the aggregate, amount to significant
potential liability which, if adjudicated in a manner adverse to the Company in
one reporting period, could have a material adverse effect on the Company's cash
flow or operations for that period. Although the outcome of these contingencies
or the probability of the occurrence of these contingencies cannot be predicted
with certainty, the Company does not expect these matters to have a material
adverse effect on its financial position.
13. BUSINESS SEGMENTS
The Company conducts its operations through two industry segments:
exploration and production ("E&P"), and gas transportation ("Transportation").
The E&P segment explores for, develops, produces and markets natural gas,
condensate and natural gas liquids. The Transportation segment engages in
intrastate natural gas transportation and marketing. All of the Company's
significant gas and oil operations are located in Webb, Zapata and Starr
Counties, Texas. Segment income excludes interest income, interest expense and
unallocated general corporate expenses. Identifiable assets are those assets
used in the operations of the segment. Other assets consist primarily of debt
issue costs, certain receivables and other property and equipment. The Company's
revenues are derived principally from sales to interstate and intrastate gas
pipelines, direct end users, industrial companies, marketers, and refiners
located in the United States. As a general policy, collateral is not required
for receivables, but customers' financial condition and credit worthiness are
regularly evaluated. The Company is not aware of any significant credit risk
relating to its customers and has not experienced significant credit losses
associated with such receivables.
For the year ended January 31, 1997, three customers provided approximately
$70 million, $59 million and $48 million, respectively, in E&P and
Transportation revenues. For the Transition Period, three customers provided
approximately $25 million, $22 million and $14 million, respectively, in E&P and
Transportation revenues. For the year ended July 31, 1995, two customers
provided approximately $73 million and $41 million, respectively, in E&P and
Transportation revenues. In 1994, one customer provided approximately $51
million in E&P and Transportation revenues.
25
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Business segment information is as follows (in thousands of dollars):
DEPRECIATION
OPERATING DEPLETION
INCOME AND CAPITAL IDENTIFIABLE
NET SALES (LOSS) AMORTIZATION EXPENDITURES ASSETS
--------- --------- ------------ ------------ ------------
YEAR ENDED JANUARY 31, 1997
Exploration and production.... $363,459 $230,560 $122,570 $314,013 $ 884,638
Gas transportation............ 42,200 (9,018) 8,466 33,636 98,903
Other......................... 688 (34,263) 1,417 11,165 69,611
-------- -------- -------- -------- ----------
$406,347 $187,279 $132,453 $358,814 $1,053,152
======== ======== ======== ======== ==========
YEAR ENDED JANUARY 31,
1996(unaudited)
Exploration and production.... $256,986 $ 81,438 $111,993 $335,903 $ 739,345
Gas transportation............ 33,518 (4,362) 8,204 17,005 72,815
Other......................... 834 (15,022) 316 20,228 126,667
-------- -------- -------- -------- ----------
$291,338 $ 62,054 $120,513 $373,136 $ 938,827
======== ======== ======== ======== ==========
TRANSITION PERIOD ENDED JANUARY
31, 1996
Exploration and production.... $124,663 $ 51,443 $ 56,543 $176,386 $ 739,345
Gas transportation............ 15,892 (4,393) 4,194 13,266 72,815
Other......................... 601 (7,802) 157 15,836 126,667
-------- -------- -------- -------- ----------
$141,156 $ 39,248 $ 60,894 $205,488 $ 938,827
======== ======== ======== ======== ==========
SIX MONTHS ENDED JANUARY 31,
1995(unaudited)
Exploration and production.... $143,304 $ 32,860 $ 66,175 $ 99,672 $ 483,984
Gas transportation............ 19,161 2,796 4,031 6,366 63,541
Other......................... 52 (6,972) 139 4,804 47,213
-------- -------- -------- -------- ----------
$162,517 $ 28,684 $ 70,345 $110,842 $ 594,738
======== ======== ======== ======== ==========
YEAR ENDED JULY 31, 1995
Exploration and production.... $275,627 $ 62,855 $121,625 $259,189 $ 712,322
Gas transportation............ 36,787 2,827 8,041 10,105 60,916
Other......................... 285 (14,192) 298 9,196 53,332
-------- -------- -------- -------- ----------
$312,699 $ 51,490 $129,964 $278,490 $ 826,570
======== ======== ======== ======== ==========
YEAR ENDED JULY 31, 1994
Exploration and production.... $302,522 $ 96,828 $107,727 $180,426 $ 464,190
Gas transportation............ 33,240 (2,257) 5,913 35,763 66,019
Other......................... 157 (15,280) 218 25,079 53,382
-------- -------- -------- -------- ----------
$335,919 $ 79,291 $113,858 $241,268 $ 583,591
======== ======== ======== ======== ==========
26
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Summary Information
The following summary financial information of TransTexas Transmission
Corporation reflects its financial position and its results of operations for
the periods presented (in thousands of dollars):
JANUARY 31,
---------------------
1997 1996
-------- -------
ASSETS
Total current assets........................................ $ 1,831 $ 811
Property and equipment, net................................. 482,351 70,273
Other assets................................................ 6,004 3
-------- -------
$490,186 $71,087
======== =======
LIABILITIES AND EQUITY
Total current liabilities................................... $ 14,013 $ 6,191
Total noncurrent liabilities................................ 107,367 34,284
Total equity................................................ 368,806 30,612
-------- -------
$490,186 $71,087
======== =======
In January 1997, the Company contributed to TTC certain Lobo Trend
properties, and related liabilities, with historical costs of approximately
$386.7 million.
YEAR ENDED SIX MONTHS ENDED YEAR ENDED
JANUARY 31, JANUARY 31, JULY 31,
---------------------- --------------------- ------------------
1997 1996 1996 1995 1995 1994
-------- ----------- ------- ----------- -------- -------
(UNAUDITED) (UNAUDITED)
Revenues................... $107,921 $ 81,034 $36,226 $53,120 $ 97,928 $77,915
Operating costs and
expenses................. 100,105 71,947 35,236 40,443 77,154 79,566
-------- -------- ------- ------- -------- -------
Operating income
(loss)................ 7,816 9,087 990 12,677 20,774 (1,651)
Interest income (expense),
net...................... (8,598) (13,196) (4,202) (2,777) (11,771) (4,483)
-------- -------- ------- ------- -------- -------
Income (loss) before
income taxes.......... (782) (4,109) (3,212) 9,900 9,003 (6,134)
Income tax expense
(benefit)................ (274) (1,438) (1,124) 3,465 3,151 (2,067)
-------- -------- ------- ------- -------- -------
Net income (loss)........ $ (508) $ (2,671) $(2,088) $ 6,435 $ 5,852 $(4,067)
======== ======== ======= ======= ======== =======
TTC conducts significant intercompany activities with TransTexas Gas
Corporation and TransAmerican. Included in the results of operations of
Transmission are the following transactions with affiliates (in thousands of
dollars):
YEAR ENDED SIX MONTHS ENDED YEAR ENDED
JANUARY 31, JANUARY 31, JULY 31,
--------------------- --------------------- -----------------
1997 1996 1996 1995 1995 1994
------- ----------- ------- ----------- ------- -------
(UNAUDITED) (UNAUDITED)
Revenues........................ $24,848 $31,691 $14,879 $18,242 $35,054 $30,398
Operating costs and expenses.... 77,204 52,235 24,751 32,235 59,719 53,459
27
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Affiliated operating costs and expenses for the years ended January 31,
1997 and 1996, include the cost of natural gas purchased from TransTexas Gas
Corporation and its predecessor of approximately $49 million and $36 million,
respectively, $16 million and $25 million, respectively, for the six months
ended January 31, 1996 and 1995 and $44 million and $34 million, respectively,
for the years ended July 31, 1995 and 1994. Nonaffiliated revenues include the
sales of natural gas liquids and condensate extracted from this purchased gas
of, $62 million and $46 million, respectively for the years ended January 31,
1997 and 1996, $20 million and $33 million, respectively, for the six months
ended January 31, 1996 and 1995 and $59 million and $44 million, respectively,
for the years ended July 31, 1995 and 1994.
14. LITIGATION SETTLEMENTS
Bentsen. On August 13, 1990, Calvin R. Bentsen, et al. filed suit against
TransAmerican and Mr. Stanley in the 139th Judicial District Court, Hidalgo
County, Texas, seeking a portion of the El Paso settlement proceeds, and an
accounting of monies allegedly owed to them, claiming that TransAmerican
produced gas that belonged to them without their knowledge and that
TransAmerican entered into an oral agreement with them which entitled them to
receive a portion of the El Paso settlement proceeds. This case has been
settled.
McNamara. On June 28, 1996, the Company consummated a settlement of
litigation with Tennessee Gas Pipeline Company ("Tennessee") that was filed on
October 14, 1993 in the 244th Judicial District Court, Ector County, Texas
pursuant to which the Company and another plaintiff received approximately $125
million from Tennessee. The Company's share of the settlement proceeds was $96
million. On July 2, 1996, John McNamara, Jr. et al. ("The Hubberd Trusts") filed
a new suit against the Company in the 241st District Court, Webb County, Texas
asserting that the Company had breached its duties to The Hubberd Trusts under
certain oil and gas leases and that the Company owed The Hubberd Trusts 25% of
the gross settlement proceeds, or approximately $31.25 million. This litigation
was settled in December 1996.
Kathryn M. On June 8, 1995, Kathryn M., Inc., et al., filed suit against
TransAmerican in the 333rd Judicial District Court (subsequently transferred to
the 334th Judicial District Court), Harris County, Texas, alleging that the
plaintiffs, as nonparticipating royalty interest owners in certain leases, are
entitled to receive a portion of the settlement proceeds received by
TransAmerican from El Paso. On April 16, 1996, additional nonparticipating
royalty interest owners intervened, making the same claims as the plaintiffs. In
June 1996, TransAmerican filed its motion for summary judgment. Plaintiffs also
filed a motion for partial summary judgment. On August 2, 1996, the court denied
TransAmerican's motion and plaintiffs' motion. The plaintiffs and intervenors
agreed on November 15, 1996 to dismiss their claims without prejudice.
Terry/Penrod. TransAmerican and a group of TransAmerican's former bank
lenders (the "Bank Group") were parties to a consolidated suit filed December 6,
1991, in the United States District Court for the Southern District of Texas,
Houston Division, relating to the interpretation of two third-party drilling
agreements. Plaintiffs Ensco Offshore Company, f/k/a Penrod Drilling
Corporation, Terry Oilfield Supply Co., Inc. and Terry Resources, Inc. ("Terry")
sued TransAmerican for approximately $50 million in actual damages and punitive
damages of not less than five times actual damages. On April 5, 1996, the court
entered a final judgment against TransAmerican, the Company and several of their
affiliates, in the amount of approximately $43 million, plus interest. On April
18, 1996, the court entered a separate judgment against the same parties for
Terry's attorneys' fees of $2 million. In May 1996, the Company paid Terry
approximately $19 million and caused escrowed funds held for the benefit of the
Bank Group of approximately $22 million to be paid to Terry. Upon payment of the
settlement amount, Terry released the judgments, released all liens and
reassigned to the Company a production payment in certain properties. Terry
dismissed an unrelated administrative proceeding upon payment of the settlement
amount described above.
Ginther/Warren. Wilbur L. Ginther and Howard C. Warren conveyed a portion
of a lease to Henry J. N. Taub. Taub "farmed out" certain interests to
TransAmerican, and TransAmerican paid royalties to Taub. The Texas Supreme Court
upheld a judgment in favor of Messrs. Ginther and Warren against Taub's interest
in
28
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
the lease. The lower court judgment had awarded a portion of the lease to
Messrs. Ginther and Warren because Taub's attorney had defrauded Messrs. Ginther
and Warren with respect to their interest in the lease. On November 26, 1986,
the estates of Messrs. Ginther and Warren filed an adversary proceeding in the
United States Bankruptcy Court for the Southern District of Texas, Houston
Division (the "Bankruptcy Court") against TransAmerican seeking damages and
claiming that TransAmerican had constructive notice of their disputes but
continued to pay royalties and proceeds of production to Taub. TransAmerican
filed an interpleader action in the Bankruptcy Court and deposited the disputed
funds accruing from and after November 1984 into the registry of the court. On
September 30, 1993, the Bankruptcy Court entered a judgment against
TransAmerican in the amount of $6.3 million plus post judgment interest. On
September 15, 1995, the U.S. District Court for the Southern District of Texas
entered an order reversing an award of interest to Taub and affirming the final
judgment in all other respects. The Company appealed the judgment to the Fifth
Circuit Court of Appeals. On July 2, 1996, the Company and the estates of
Messrs. Ginther and Warren entered into a settlement pursuant to which such
estates received $3.5 million and a promissory note for $2.8 million. The
promissory note is payable in 36 equal monthly installments commencing August 1,
1996, and bears no interest unless an installment payment is not made. In
addition, the Company transferred to such estates an additional overriding
royalty interest in a portion of the lease and agreed to drill additional wells
on the lease. In conjunction with the settlement, the estates of Messrs. Ginther
and Warren agreed to farm out to the Company an additional working interest in
the lease.
15. CREDIT AGREEMENTS
The Company and BNY Financial Corporation entered into an Amended and
Restated Accounts Receivable Management and Security Agreement ("BNY Facility"),
as of October 31, 1995, for a $40 million line of credit. The BNY Facility was
subsequently amended in December 1996. The line of credit is collateralized by
accounts receivable and inventory of the Company and is guaranteed by John R.
Stanley. The amounts that may be advanced to the Company under this line of
credit are based on a percentage of the Company's natural gas receivables from
unaffiliated third parties. The amount outstanding under the line of credit as
of January 31, 1997 was $26.3 million. The Company expects that it will maintain
or increase this level of borrowings under the Agreement for the next twelve
months.
Under the terms of the BNY Facility, as amended, the Company's net loss
(including any extraordinary losses) may not exceed $10 million for each
six-month period ending on the last day of any fiscal quarter ending after
January 31, 1996. This line of credit is also subject to certain other covenants
which relate to, among other things, the maintenance of certain financial
ratios.
In May 1996, the Company entered into a Note Purchase Agreement pursuant to
which the Company issued notes in the aggregate principal amount of $15.75
million, for aggregate proceeds of $15 million. The notes, which bore interest
at 13 1/3% per annum, were paid in full in July 1996. The notes were guaranteed
on a senior secured basis by TransAmerican.
16. HEDGING AGREEMENTS
Beginning in April 1995, the Company entered into commodity price swap
agreements (the "Hedge Agreements") to reduce its exposure to price risk in the
spot market for natural gas. Pursuant to the Hedge Agreements, either the
company or the counterparty thereto is required to make a payment to the other
at the end of each month (the "Settlement Date"). The payments will equal the
product of a notional quantity ("Base Quantity") of natural gas and the
difference between a specified fixed price ("Fixed Price") and a market price
("Floating Price") for natural gas. The Floating Price is determined by
reference to natural gas futures contracts traded on the New York Mercantile
Exchange ("NYMEX"). The Hedge Agreements provide for the Company to make
payments to the counterparty to the extent that the Floating Price exceeds the
Fixed Price, up to a maximum ("Maximum Floating Price") and for the counterparty
to make payments
29
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
to the Company to the extent that the Floating Price is less than the Fixed
Price. For the year ended January 31, 1997, the Company made net settlement
payments totaling approximately $37 million to the counterparty pursuant to the
Hedge Agreements. As of January 31, 1997, the Company has Hedge Agreements with
Settlement Dates ranging from February 1997 through April 1997 involving total
Base Quantities for all monthly periods aggregating approximately 20.4 TBtu of
natural gas. Fixed Prices for these agreements range from $1.70 to $1.78 per
MMBtu ($1.76 to $1.84 per Mcf) up to Maximum Floating Prices ranging from $2.00
to $2.20 per MMBtu ($2.07 to $2.28 per Mcf). In addition, one agreement has a
Fixed Price of $2.48 per MMBtu ($2.57 per Mcf) with no Maximum Floating Price.
Under the terms of this agreement, the counterparty advanced $5 million to the
Company. At January 31, 1997, the estimated cost to settle all of the Hedge
Agreements would have been approximately $13 million. These agreements are
accounted for as hedges and accordingly, any gains or losses are deferred and
recognized in the respective months as physical volumes are sold. At January 31,
1997, the Company maintained $1.0 million in a margin account related to the
Hedge Agreements.
17. SUPPLEMENTAL GAS AND OIL DISCLOSURE (UNAUDITED)
The accompanying tables present information concerning the Company's gas
and oil producing activities and are prepared in accordance with Statement of
Financial Accounting Standards No. 69, "Disclosures about Oil and Gas Producing
Activities."
Estimates of the Company's proved reserves and proved developed reserves
were prepared by Netherland, Sewell & Associates, Inc., an independent firm of
petroleum engineers, based on data supplied to them by the Company. Such
estimates are inherently imprecise and may be subject to substantial revisions
as additional information such as reservoir performance, additional drilling,
technological advancements and other factors become available.
Capitalized costs relating to gas and oil producing activities are as
follows (in thousands of dollars):
JANUARY 31,
------------------------
1997 1996
---------- ----------
Proved properties........................................... $1,845,994 $1,639,237
Unproved properties......................................... 158,973 136,360
---------- ----------
Total..................................................... 2,004,967 1,775,597
Less accumulated depletion.................................. 1,288,860 1,165,943
---------- ----------
$ 716,107 $ 609,654
========== ==========
Costs incurred for gas and oil producing activities are as follows (in
thousands of dollars):
YEAR
ENDED SIX MONTHS ENDED YEAR ENDED JULY 31,
JANUARY 31, JANUARY 31, -------------------
1997 1996 1995 1994
----------- ---------------- -------- --------
Property acquisitions................ $ 50,963 $ 11,485 $124,956 $ 18,593
Exploration.......................... 100,737 27,039 84,201 114,266
Development.......................... 162,313 115,812 50,032 47,567
-------- -------- -------- --------
$314,013 $154,336 $259,189 $180,426
======== ======== ======== ========
30
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Results of operations for gas and oil producing activities are as follows
(in thousands of dollars):
YEAR YEAR ENDED
ENDED SIX MONTHS ENDED JULY 31,
JANUARY 31, JANUARY 31, -------------------
1997 1996 1995 1994
----------- ---------------- -------- --------
Revenues............................. $363,459 $124,663 $275,627 $302,522
-------- -------- -------- --------
Expenses:
Production costs................... 97,619 31,376 76,798 76,928
Depletion.......................... 122,570 56,543 121,625 107,727
General and administrative......... 8,710 3,601 14,349 21,039
Litigation settlement.............. (96,000) (18,300) -- --
-------- -------- -------- --------
Total operating expenses........ 132,899 73,220 212,772 205,694
-------- -------- -------- --------
Income before income taxes...... 230,560 51,443 62,855 96,828
Income taxes......................... 80,696 18,005 21,999 26,047
-------- -------- -------- --------
$149,864 $ 33,438 $ 40,856 $ 70,781
======== ======== ======== ========
Depletion rate per net equivalent
Mcf................................ $ .96 $ .82 $ .81 $ .80
======== ======== ======== ========
Reserve Quantity Information
Proved reserves are estimated quantities of natural gas, condensate and
natural gas liquids that geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under existing economic and operating conditions. Proved developed reserves are
those proved reserves that can be expected to be recovered through existing
wells with existing equipment and operating conditions. Natural gas quantities
represent wet gas volumes, which include amounts that will be extracted as
natural gas liquids. The Company's estimated net proved reserves and proved
developed reserves of natural gas (billions of cubic feet) and condensate
(millions of barrels) are shown in the table below.
SIX MONTHS
YEAR ENDED ENDED YEAR ENDED JULY 31,
JANUARY 31, JANUARY 31, ----------------------------
1997 1996 1995 1994
------------ ------------- ------------- ------------
GAS OIL GAS OIL GAS OIL GAS OIL
------ --- ------- --- ------- --- ------ ---
Proved reserves:
Beginning of year........................ 1,139.1 2.9 1,122.6 3.0 717.4 1.9 695.0 2.0
Increase (decrease) during the year
attributable to:
Revisions of previous estimates....... 6.5 .1 43.0 -- 143.5 .5 .5 .1
Extensions, discoveries and other
additions........................... 90.3 3.6 73.8 .2 409.6 1.2 152.8 .4
Litigation settlement................. -- -- 9.5 -- -- -- -- --
Sales of reserves..................... (204.9) (.4) (42.9)
Purchase of reserves.................. 11.3 .1
Production............................ (122.6) (.6) (66.9) (.3) (147.9) (.6) (130.9) (.6)
------ --- ------- --- ------- --- ------ ---
End of year.............................. 919.7 5.7 1,139.1 2.9 1,122.6 3.0 717.4 1.9
====== === ======= === ======= === ====== ===
Proved developed reserves:
Beginning of year........................ 425.3 .9 476.6 1.1 442.2 1.1 384.2 1.1
End of year.............................. 381.5 2.4 425.3 .9 476.6 1.1 442.2 1.1
31
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Standardized Measure Information
The calculation of estimated future net cash flows in the following table
assumed the continuation of existing economic conditions and applied year-end
prices (except for future price changes as allowed by contract) of gas and
condensate to the expected future production of such reserves, less estimated
future expenditures (based on current costs) to be incurred in developing and
producing those proved reserves.
The standardized measure of discounted future net cash flows does not
purport, nor should it be interpreted, to present the fair market value of the
Company's gas and oil reserves. These estimates reflect proved reserves only and
ignore, among other things, changes in prices and costs, revenues that could
result from probable reserves which could become proved reserves in fiscal 1998
or later years, and the risks inherent in reserve estimates. The standardized
measure of discounted future net cash flows relating to proved gas and oil
reserves is as follows (in thousands of dollars):
SIX MONTHS
YEAR ENDED ENDED YEAR ENDED JULY 31,
JANUARY 31, JANUARY 31, -----------------------
1997 1996 1995 1994
----------- ----------- ---------- ----------
Future cash inflows.................. $3,051,397 $2,269,585 $1,591,011 $1,194,656
Future production costs.............. (506,882) (427,482) (316,055) (219,485)
Future development costs............. (459,326) (582,798) (461,471) (243,991)
Future income taxes.................. (563,812) (310,445) (196,942) (199,065)
---------- ---------- ---------- ----------
Future net cash flows................ 1,521,377 948,860 616,543 532,115
Annual discount (10%) for estimated
timing of cash flows............... (464,121) (340,002) (201,479) (136,541)
---------- ---------- ---------- ----------
Standardized measure of discounted
future net cash flows.............. $1,057,256 $ 608,858 $ 415,064 $ 395,574
========== ========== ========== ==========
Principal sources of change in the standardized measure of discounted
future net cash flows are as follows (in thousands of dollars):
SIX MONTHS
YEAR ENDED ENDED YEAR ENDED JULY 31,
JANUARY 31, JANUARY 31, ---------------------
1997 1996 1995 1994
----------- ----------- --------- ---------
Beginning of year..................... $ 608,858 $ 415,064 $ 395,574 $ 512,460
Revisions:
Quantity estimates and production
rates............................ 13,903 31,712 122,771 (31,403)
Prices, net of lifting costs........ 665,054 331,936 (155,257) (158,906)
Estimated future development
costs............................ (75,622) (128,584) (13,631) 26,667
Additions, extensions, discoveries and
improved recovery................... 209,932 47,026 172,365 141,008
Net sales of production............... (262,066) (92,139) (198,829) (233,031)
Development costs incurred............ 156,430 115,812 49,873 35,285
Accretion of discount................. 80,806 27,382 54,439 63,824
Net changes in income taxes........... (192,608) (66,622) (16,722) 39,670
Sale of Reserves...................... (165,949) (77,879) -- --
Litigation settlement................. -- 5,150 4,481 --
Purchases of reserves................. 18,518 -- -- --
---------- --------- --------- ---------
End of year........................... $1,057,256 $ 608,858 $ 415,064 $ 395,574
========== ========= ========= =========
32
TRANSTEXAS GAS CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Year-end wellhead prices received by the Company from sales of natural gas
including margins from natural gas liquids, were $3.17, $1.95, $1.37 and $1.62
per Mcf for 1997, 1996, 1995 and 1994, respectively. Year-end condensate prices
were $23.99, $18.34, $16.27 and $17.62 per barrel for 1996, 1995 and 1994,
respectively.
18. CONSOLIDATED SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)
1997 1996 1995
--------------------------------------- --------------------- --------------------------------------
1ST 2ND 3RD 4TH 1ST 2ND 1ST 2ND 3RD 4TH
QUARTER QUARTER QUARTER QUARTER QUARTER QUARTER QUARTER QUARTER QUARTER QUARTER
------- -------- ------- -------- ---------- -------- ------- ------- ------- --------
(RESTATED)
(IN THOUSANDS, EXCEPT PER SHARE DATA)
Revenues................. $95,958 $ 86,732 $80,104 $143,553 $66,336 $ 74,346 $81,450 $81,067 $72,828 $ 77,354
Operating income......... 25,798 106,696 5,858 48,927 30,893 7,881 14,108 14,576 12,932 9,874
Net income (loss)........ 3,020 71,561 (9,396) 18,140 11,529 (12,301) 316 (560) (3,844) (64,441)
Net income (loss) per
share.................. 0.04 0.97 (0.13) 0.25 0.16 (0.17) -- (.01) (.05) (.87)
Operating income for the second quarter of 1997 includes a gain on
settlement of litigation of $96.0 million.
Operating income for the third quarter of 1997 includes litigation expense
of $7.5 million.
Operating income for the first quarter of 1996 includes a gain on
settlement of litigation of $18.3 million.