================================================================================
- -------------------------------------------------------------------------------
- -------------------------------------------------------------------------------
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 1998
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from __________ to __________
Commission file number 1-7176
THE COASTAL CORPORATION
(Exact name of registrant as specified in its charter)
Delaware 74-1734212
(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
Coastal Tower
Nine Greenway Plaza
Houston, Texas 77046-0995
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (713) 877-1400
---------------------------
Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months, and (2) has been subject to such filing
requirements for the past 90 days. Yes X No _____
As of April 30, 1998, there were outstanding 105,863,977 shares of Common
Stock, 33-1/3 cents par value per share, and 361,192 shares of Class A Common
Stock, 33-1/3 cents par value per share, of the Registrant.
<PAGE>
PART I
FINANCIAL INFORMATION
Item 1. Financial Statements.
The financial statements of The Coastal Corporation ("Coastal") and its
subsidiaries (collectively, the "Company") are presented herein and are
unaudited, except for balances as of December 31, 1997, and therefore are
subject to year-end adjustments; however, all adjustments which are, in the
opinion of management, necessary for a fair statement of the results of
operations for the periods covered have been made. The adjustments which have
been made are of a normal recurring nature. Such results are not necessarily
indicative of results to be expected for the year due to seasonal variations and
market conditions affecting sales of natural gas and petroleum products.
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Millions of Dollars)
<CAPTION>
March 31, December 31,
ASSETS 1998 1997
--------------- -------------
(Unaudited)
<S> <C> <C>
Current Assets:
Cash and cash equivalents............................................... $ 20.0 $ 20.5
Receivables, less allowance for doubtful accounts of $15.8 million
(1998) and $16.6 million (1997)...................................... 1,168.9 1,570.8
Inventories............................................................. 543.7 684.7
Prepaid expenses and other.............................................. 254.4 252.7
----------- -----------
Total Current Assets................................................. 1,987.0 2,528.7
----------- -----------
Property, Plant and Equipment - at cost:
Natural gas systems..................................................... 5,900.4 5,859.0
Refining, crude oil and chemical facilities............................. 2,308.9 2,254.8
Gas and oil properties - at full-cost................................... 2,316.2 2,152.0
Other................................................................... 401.9 395.0
----------- -----------
10,927.4 10,660.8
Accumulated depreciation, depletion and amortization.................... 3,617.8 3,539.2
----------- -----------
7,309.6 7,121.6
----------- -----------
Other Assets:
Goodwill................................................................ 485.0 489.8
Investments - equity method............................................. 763.5 722.8
Other................................................................... 764.1 762.3
----------- -----------
2,012.6 1,974.9
----------- -----------
$ 11,309.2 $ 11,625.2
=========== ===========
</TABLE>
See Notes to Consolidated Financial Statements.
- 1 -
<PAGE>
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Millions of Dollars)
<CAPTION>
March 31, December 31,
LIABILITIES AND STOCKHOLDERS' EQUITY 1998 1997
--------------- --------------
(Unaudited)
<S> <C> <C>
Current Liabilities:
Notes payable........................................................... $ 108.0 $ 114.0
Accounts payable........................................................ 1,491.0 2,074.0
Accrued expenses........................................................ 355.0 270.7
Current maturities on long-term debt.................................... 12.0 42.0
------------ ------------
Total Current Liabilities............................................ 1,966.0 2,500.7
------------ ------------
Debt:
Long-term debt, excluding current maturities............................ 3,759.2 3,663.2
------------ ------------
Deferred Credits and Other:
Deferred income taxes................................................... 1,606.8 1,564.9
Other deferred credits.................................................. 484.3 514.0
------------ ------------
2,091.1 2,078.9
------------ ------------
Preferred Stock:
Issued by subsidiaries.................................................. 100.0 100.0
------------ ------------
Common Stock and Other Stockholders' Equity:
Cumulative preferred stock (with aggregate liquidation preference
of $208.1 million)................................................... 2.6 2.6
Class A common stock.................................................... .1 .1
Common stock............................................................ 72.1 36.7
Additional paid-in capital.............................................. 1,210.7 1,243.6
Retained earnings....................................................... 2,239.9 2,131.9
------------ ------------
3,525.4 3,414.9
Less common stock in treasury - at cost................................. 132.5 132.5
------------ ------------
3,392.9 3,282.4
------------ ------------
$ 11,309.2 $ 11,625.2
============ ============
</TABLE>
See Notes to Consolidated Financial Statements.
- 2 -
<PAGE>
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED OPERATIONS
(Millions of Dollars, Except Per Share)
<CAPTION>
Three Months Ended
March 31,
---------------------
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Operating Revenues...................................................................... $ 1,956.5 $ 3,205.8
--------- ---------
Operating Costs and Expenses:
Purchases............................................................................ 1,186.4 2,465.4
Operating and general expenses....................................................... 422.1 419.5
Depreciation, depletion and amortization............................................. 107.0 115.9
--------- ---------
1,715.5 3,000.8
--------- ---------
Other Income - net...................................................................... 19.4 24.6
--------- ---------
Earnings Before Interest and Income Taxes............................................... 260.4 229.6
--------- ---------
Interest and Debt Expense, less $5.5 million (1998)
and $2.4 million (1997) capitalized.................................................. 75.3 79.2
Taxes on Income......................................................................... 62.2 49.2
--------- ---------
Earnings Before Extraordinary Item...................................................... 122.9 101.2
Extraordinary item - loss on early extinguishment of debt............................... - (90.6)
--------- ---------
Net Earnings............................................................................ 122.9 10.6
Dividends on Preferred Stock............................................................ 4.3 4.3
--------- ---------
Net Earnings Available
to Common Stockholders............................................................... $ 118.6 $ 6.3
========= =========
Basic Earnings Per Share:
Before extraordinary item............................................................ $ .56 $ .46
Extraordinary item................................................................... - (.43)
--------- ---------
Net Basic Earnings Per Share......................................................... $ .56 $ .03
========= =========
Diluted Earnings Per Share:
Before extraordinary item............................................................ $ .55 $ .45
Extraordinary item................................................................... - (.42)
--------- ---------
Net Diluted Earnings Per Share....................................................... $ .55 $ .03
========= =========
Cash Dividends Per Common Share......................................................... $ .05 $ .05
========= =========
</TABLE>
See Notes to Consolidated Financial Statements.
- 3 -
<PAGE>
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED COMMON STOCK AND OTHER STOCKHOLDERS' EQUITY
(Thousands of Shares and Millions of Dollars)
<CAPTION>
Three Months Ended March 31,
------------------------------------------------------
1998 1997
------------------------ ------------------------
Shares Amount Shares Amount
---------- ---------- ---------- ----------
(Unaudited)
<S> <C> <C> <C> <C>
Preferred stock, par value
33-1/3(cent) per share, authorized 50,000,000 shares:
Cumulative convertible preferred:
$1.19, Series A, redemption or liquidation
amount of $33 per share:
Beginning balance........................... 58 $ - 60 $ -
Converted to common......................... - - (1) -
----------- ---------- ----------- ----------
Ending balance.............................. 58 - 59 -
=========== ---------- =========== ----------
$1.83, Series B, redemption or liquidation
amount of $50 per share:
Beginning balance........................... 68 - 74 -
Converted to common......................... (2) - (2) -
----------- ---------- ----------- ----------
Ending balance.............................. 66 - 72 -
=========== ---------- =========== ----------
$5.00, Series C, redemption or liquidation
amount of $100 per share:
Beginning balance........................... 30 - 32 -
Converted to common......................... (1) - - -
----------- ---------- ----------- ----------
Ending balance.............................. 29 - 32 -
=========== ---------- =========== ----------
Cumulative preferred:
$2.125, Series H, liquidation amount
of $25 per share:
Beginning and ending balance................ 8,000 2.6 8,000 2.6
=========== ---------- =========== ----------
Class A common stock, par value 331/3(cent) per share,
authorized 2,700,000 shares:
Beginning balance................................ 366 .1 382 .1
Converted to common.............................. (3) - (2) -
----------- ---------- ----------- ----------
Ending balance................................... 363 .1 380 .1
=========== ---------- =========== ----------
Common stock, par value 331/3(cent) per share,
authorized 250,000,000 shares:
Beginning balance................................ 110,117 36.7 109,756 36.6
Conversion of preferred stock.................... 7 - 8 -
Conversion of Class A common stock............... 3 - 2 -
Two-for-one stock split.......................... 106,179 35.4 - -
Exercise of stock options........................ 85 - 95 -
----------- ---------- ----------- ----------
Ending balance................................... 216,391 $ 72.1 109,861 $ 36.6
=========== ---------- =========== ----------
</TABLE>
See Notes to Consolidated Financial Statements.
- 4 -
<PAGE>
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED COMMON STOCK AND OTHER STOCKHOLDERS' EQUITY
(Thousands of Shares and Millions of Dollars)
(Continued)
<CAPTION>
Three Months Ended March 31,
------------------------------------------------------
1998 1997
------------------------ ------------------------
Shares Amount Shares Amount
---------- ---------- ---------- ----------
(Unaudited)
<S> <C> <C> <C> <C>
Additional paid-in capital:
Beginning balance................................... $ 1,243.6 $ 1,239.6
Exercise of stock options........................... 2.5 1.4
Two-for-one stock split............................. (35.4) -
---------- ----------
Ending balance...................................... 1,210.7 1,241.0
---------- ----------
Retained earnings:
Beginning balance................................... 2,131.9 1,890.1
Net earnings for period............................. 122.9 10.6
Dividends on preferred stock........................ (4.3) (4.3)
Dividends on common stock........................... (10.6) (10.6)
---------- ----------
Ending balance...................................... 2,239.9 1,885.8
---------- ----------
Less treasury stock - at cost.......................... 4,396 132.5 4,395 132.5
=========== ---------- =========== ----------
Total.................................................. $ 3,392.9 $ 3,033.6
========== ==========
</TABLE>
See Notes to Consolidated Financial Statements.
- 5 -
<PAGE>
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS
(Millions of Dollars)
<CAPTION>
Three Months Ended
March 31,
--------------------------
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Net Cash Flow From Operating Activities:
Earnings before extraordinary item.......................................... $ 122.9 $ 101.2
Add (subtract) items not requiring (providing) cash:
Depreciation, depletion and amortization................................. 107.9 116.8
Deferred income taxes.................................................... 33.5 4.6
Undistributed earnings from equity investments........................... (5.4) (8.1)
Working capital and other changes, excluding changes relating to cash and
non-operating activities:
Accounts receivable................................................... 401.9 .1
Inventories........................................................... 140.9 371.8
Prepaid expenses and other............................................ (10.6) 5.7
Accounts payable...................................................... (581.1) (243.0)
Accrued expenses...................................................... 83.5 (50.9)
Other................................................................. (18.0) 14.1
--------- --------
275.5 312.3
--------- --------
Cash Flow From Investing Activities:
Purchases of property, plant and equipment.................................. (287.2) (142.7)
Proceeds from sale of property, plant and equipment......................... .6 2.7
Additions to investments.................................................... (37.7) (92.2)
Proceeds from investments................................................... .7 4.4
--------- --------
(323.6) (227.8)
--------- --------
Cash Flow From Financing Activities:
Increase in short-term notes ............................................... 194.0 400.0
Proceeds from issuing common stock.......................................... 2.5 1.4
Proceeds from long-term debt issues......................................... .7 527.7
Payments to retire long-term debt........................................... (134.7) (995.5)
Dividends paid.............................................................. (14.9) (14.9)
--------- --------
47.6 (81.3)
--------- --------
Net Increase (Decrease) in Cash and Cash Equivalents........................... (.5) 3.2
Cash and Cash Equivalents at Beginning of Period............................... 20.5 106.3
--------- --------
Cash and Cash Equivalents at End of Period..................................... $ 20.0 $ 109.5
========= ========
</TABLE>
See Notes to Consolidated Financial Statements.
- 6 -
<PAGE>
THE COASTAL CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. Summary of Significant Accounting Policies
For additional information relative to operations and financial position,
reference is made to the Company's Annual Report on Form 10-K for the fiscal
year ended December 31, 1997. Certain minor reclassifications of prior period
statements have been made to conform with current reporting practices. The
effect of the reclassifications was not material to the Company's consolidated
results of operations, financial position or cash flows. In 1997, the Company
reexamined the useful lives of certain assets associated with the interstate
natural gas pipeline and storage subsidiaries. In July 1997, the depreciation
rates related to these assets were revised. This revision had the effect of
increasing "Earnings Before Extraordinary Item" and "Net Earnings" by
approximately $9.5 million ($.04 per share) for the three months ended March 31,
1998.
The Company adopted Statement of Financial Accounting Standards No. 130,
"Reporting Comprehensive Income," in 1998. The application of the new standard
did not have a material effect on the Company's consolidated financial
statements as the Company currently does not have any material items of other
comprehensive income.
The Company adopted Statement of Financial Accounting Standards No. 131,
"Disclosures about Segments of an Enterprise and Related Information" ("FAS
131"), in 1998. See Note 6 for additional information on FAS 131.
The Company adopted Statement of Financial Accounting Standards No. 132,
"Employers' Disclosures about Pensions and Other Postretirement Benefits" ("FAS
132"), in 1998. FAS 132, which revises employer disclosures regarding pension
plans and other postretirement plans, is not expected to have a material effect
on the Company's consolidated financial statements.
The Accounting Standards Executive Committee of the American Institute of
Certified Public Accountants ("AICPA") has issued Statement of Position 98-1,
"Accounting for the Costs of Computer Software Developed or Obtained for
Internal Use" ("SOP 98-1"), to be effective for periods beginning after December
15, 1998. The Company adopted SOP 98-1 in 1998. SOP 98-1 establishes standards
for the treatment of costs associated with software developed or obtained for
internal use. SOP 98-1 is not expected to have a material effect on the
Company's consolidated financial statements.
The AICPA has issued Statement of Position 98-5, "Reporting on the Costs
of Start-Up Activities" ("SOP 98-5"), to be effective for periods beginning
after December 15, 1998. SOP 98-5 provides guidance on accounting for costs
incurred to open new facilities, conduct business in new territories or
otherwise commence some new operation. The application of SOP 98-5 is not
expected to have a material effect on the Company's consolidated financial
statements.
Supplemental information relative to the Statement of Consolidated Cash
Flows includes the following: the Company made cash payments for interest and
financing fees, net of amounts capitalized, of $63.1 million and $80.6 million
for the three months ended March 31, 1998 and 1997, respectively. Cash payments
for income taxes amounted to $1.8 million and $36.6 million for the three months
ended March 31, 1998 and 1997, respectively.
2. Inventories
Inventories were as follows (millions of dollars):
<TABLE>
<CAPTION>
March 31, December 31,
1998 1997
--------------- --------------
(Unaudited)
<S> <C> <C>
Refined products, crude oil and chemicals............................... $ 364.2 $ 492.3
Natural gas in underground storage...................................... 29.0 40.5
Coal, materials and supplies............................................ 150.5 151.9
----------- ----------
$ 543.7 $ 684.7
=========== ==========
</TABLE>
Elements included in inventory cost are material, labor and manufacturing
expense.
- 7 -
<PAGE>
3. Stock Split
On May 7, 1998, the Board of Directors of Coastal authorized a two-for-one
stock split of the Coastal common stock. Stockholders of record will receive one
additional share of common stock for each share of common stock and/or Class A
common stock held of record on May 29, 1998. The distribution will be made on
July 1, 1998. The stock split has been reflected in the accompanying financial
statements as of March 31, 1998 and all applicable references as to the number
of common shares, and per share information has been restated. Appropriate
adjustments will be made in the conversion ratios of shares of convertible
preferred stock and in the exercise price and number of shares subject to stock
options. Effective with the stock split, the annual cash dividend rate on the
common stock will be $.25 per share. The newly issued shares will receive the
dividend at the new rate.
4. Notes Payable
At March 31, 1998, the Company had $558.0 million of outstanding
indebtedness to banks under short-term lines of credit. The Company's financial
statements at March 31, 1998, reflect $450.0 million of short-term borrowings
which have been reclassified as long-term, based on the availability of
committed credit lines with maturities in excess of one year and the Company's
intent to maintain such amounts as long-term borrowings. There was a similar
reclassification of $250.0 million as of December 31, 1997.
5. Common Stock
On March 31, 1998, 13,507,784 shares of Common Stock of the Company were
reserved for stock option plans, 1,312,554 shares were reserved for conversion
of the Series A, B, and C Preferred Stocks, 362,988 shares were reserved for
conversion of outstanding Class A Common Stock and 20,448 shares were reserved
for conversion of Class A Common Stock subject to future issuance. The Class A
Common Stock reserved for future issuance consists of 2,280 shares reserved for
employee stock option plans and 18,168 shares reserved for conversion of the
Series A, B, and C Preferred Stocks.
During the quarter ended March 31, 1998, the Company granted options to
purchase 2,060,000 common shares under stock option plans with exercise prices
ranging from $27.75 to $32.75. The exercise prices are equal to the market price
of the common shares at grant date.
6. Segment Information
The Company adopted FAS 131 in 1998. FAS 131 establishes standards for the
way that public business enterprises report information about operating segments
and requires those companies to report selected information about the operating
segments. Data for 1997 has been reclassified to conform with current reporting
practices following the standards in FAS 131 (millions of dollars):
<TABLE>
<CAPTION>
Three Months Ended
March 31,
---------------------
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Operating Revenues From External Customers:
Natural gas....................................................................... $ 413.3 $ 1,208.3
Refining, marketing and chemicals................................................. 1,353.6 1,854.0
Exploration and production........................................................ 104.4 61.4
Coal.............................................................................. 53.8 54.3
Power............................................................................. 27.8 26.0
Corporate and other............................................................... 3.6 1.8
--------- ---------
$ 1,956.5 $ 3,205.8
========= =========
</TABLE>
- 8 -
<PAGE>
Intersegment revenues were as follows: Natural gas - $2.8 million (1998),
$41.1 million (1997); Exploration and production - $8.0 million (1998), $87.6
million (1997); and Corporate and other - $2.7 million (1998), $6.2 million
(1997).
<TABLE>
<CAPTION>
Three Months Ended
March 31,
---------------------
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Earnings (Loss) Before Interest and Income Taxes:
Natural gas....................................................................... $ 193.8 $ 211.0
Refining, marketing and chemicals................................................. 47.6 (47.3)
Exploration and production........................................................ 25.5 62.2
Coal.............................................................................. 2.8 12.5
Power............................................................................. 11.6 10.4
Corporate and other............................................................... (20.9) (19.2)
--------- ---------
$ 260.4 $ 229.6
========= =========
</TABLE>
7. Income Taxes
Provisions for income taxes were as follows (millions of dollars):
<TABLE>
<CAPTION>
Three Months Ended
March 31,
---------------------
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Current Income Taxes:
Federal........................................................................... $ 21.2 $ 38.0
Foreign........................................................................... 1.5 1.5
State............................................................................. 6.0 5.1
--------- ---------
28.7 44.6
--------- ---------
Deferred Income Taxes:
Federal........................................................................... 31.5 4.5
Foreign........................................................................... .8 .9
State............................................................................. 1.2 (.8)
--------- ---------
33.5 4.6
$ 62.2 $ 49.2
========= =========
</TABLE>
Interim period provisions for federal income taxes are based on estimated
effective annual income tax rates.
- 9 -
<PAGE>
8. Earnings Per Share
Earnings per share are calculated following Statement of Financial
Accounting Standards No. 128. The following data shows the amounts used in
computing basic earnings per share and the effects on income and the weighted
average number of shares of dilutive securities.
<TABLE>
<CAPTION>
Three Months Ended March 31, 1998
------------------------------------------------
Income Shares
(Numerator) (Denominator) Per-Share
(Millions) (Thousands) Amount
-------------- ----------- -----------
(Unaudited)
<S> <C> <C> <C>
Earnings before extraordinary item...................... $ 122.9
Less preferred stock dividends.......................... 4.3
--------------
Basic earnings per share
Income available to common stockholders.............. 118.6 212,236 $ .56
===========
Effect of dilutive securities
Options.............................................. - 2,116
Convertible preferred stock.......................... .1 1,349
-------------- -----------
Diluted earnings per share
Income available to common stockholders plus
assumed conversions.............................. $ 118.7 215,701 $ .55
============== =========== ===========
</TABLE>
<TABLE>
<CAPTION>
Three Months Ended March 31, 1997
------------------------------------------------
Income Shares
(Numerator) (Denominator) Per-Share
(Millions) (Thousands) Amount
-------------- ----------- -----------
(Unaudited)
<S> <C> <C> <C>
Earnings before extraordinary item...................... $ 101.2
Less preferred stock dividends.......................... 4.3
--------------
Basic earnings per share
Income available to common stockholders.............. 96.9 211,590 $ .46
===========
Effect of dilutive securities
Options.............................................. - 1,554
Convertible preferred stock.......................... .1 1,447
-------------- -----------
Diluted earnings per share
Income available to common stockholders plus
assumed conversions.............................. $ 97.0 214,591 $ .45
============== =========== ===========
</TABLE>
9. Litigation, Regulatory and Environmental Matters
Litigation Matters
In connection with the December 20, 1996 sale of the Company's western
coal operations, the Company has assumed control of a pending dispute with the
Intermountain Power Agency ("IPA") involving two coal sales agreements of
Coastal States Energy Company, which contracts were included in the sale, and
for which the Company continues to have certain responsibilities. The dispute
involves a claim by IPA to expanded audit rights under the contracts. The
Company vigorously disputes IPA's claim and filed a counterclaim for certain
contractual payments wrongfully withheld by IPA. On July 14, 1997, IPA made a
demand for arbitration between the parties, asserting a claim of a gross
inequity under the contracts requiring a reduction in the purchase price of coal
sold before and after the sale of these coal operations. The Company believes
that no gross inequity has occurred and that it should prevail in the
arbitration on the merits. The Company has also asserted that the pending
lawsuit, which presents several common legal issues between the two proceedings,
should be resolved before any related arbitration proceeding is allowed to
proceed. A motion to this effect is pending in the U.S. District Court for Utah.
- 10 -
<PAGE>
In December 1992, certain of Colorado Interstate Gas Company's ("CIG")
natural gas lessors in the West Panhandle Field filed a complaint in the U.S.
District Court for the Northern District of Texas, claiming underpayment, breach
of fiduciary duty, fraud and negligent misrepresentation. Management believes
that CIG has numerous defenses to the lessors' claims, including (i) that the
royalties were properly paid, (ii) that the majority of the claims were released
by written agreement and (iii) that the majority of the claims are barred by the
statute of limitations. In March of 1995, the Trial Court granted a partial
summary judgment in favor of CIG, holding that the four-year statute of
limitations had not been tolled, that the releases are valid, and dismissing all
tort claims and claims for breach of any duty of disclosure. The remaining claim
for underpayment of royalties was tried to a jury which, in May 1995, made
findings favorable to CIG. On June 7, 1995, the Trial Court entered a judgment
that the lessors recover no monetary damages from CIG and permanently estopping
the lessors from asserting any claim based on an interpretation of the contract
different than that asserted by CIG in the litigation. The lessors' motion for a
new trial was denied on July 18, 1997, and both parties have filed appeals. On
June 7, 1996, the same plaintiffs sued CIG in state court in Amarillo, Texas,
for underpayment of royalties. CIG removed the second lawsuit to federal court
which granted a stay of the second suit pending the outcome of the first
lawsuit.
In October 1996, the Company, along with several subsidiaries, was named
as a defendant in a suit filed by several former and current African American
employees in the United States District Court, Southern District of Texas. The
suit alleges racially discriminatory employment policies and practices and seeks
damages in the amount of at least $100 million and punitive damages of at least
three times that amount. Plaintiffs' counsel are seeking to have the suit
certified as a class action. Coastal vigorously denies these allegations and has
filed responsive pleadings. In January 1998, the plaintiffs amended their suit
to exclude ANR Pipeline Company ("ANR Pipeline") employees from the potential
class. A new suit was then filed in state court in Wayne County, Michigan,
seeking to have the Michigan suit certified as a class action of African
American employees of ANR Pipeline and seeking unspecified damages as well as
attorneys and expert fees. ANR Pipeline has filed responsive pleadings denying
these allegations.
Numerous other lawsuits and other proceedings which have arisen in the
ordinary course of business are pending or threatened against the Company or its
subsidiaries.
Although no assurances can be given and no determination can be made at
this time as to the outcome of any particular lawsuit or proceeding, the Company
believes there are meritorious defenses to substantially all of the above claims
and that any liability which may finally be determined should not have a
material adverse effect on the Company's consolidated financial position or
results of operations.
Regulatory Matters
From November 1, 1992 to November 1, 1993, under an interim sales program,
ANR Pipeline collected monthly gas inventory demand charges ("GIC") from its
former sales customers. The GIC compensated ANR Pipeline for the fixed cost of
maintaining an inventory of gas supply in order to meet its firm sales
obligations. In April 1994, ANR Pipeline filed with the Federal Energy
Regulatory Commission ("FERC") a reconciliation report comparing its total gas
costs and revenues under the interim sales program and proposing refunds to
customers totaling $45.1 million. Certain customers disputed the level of those
refunds, and the FERC directed that a hearing be held. On March 12, 1998 the
FERC issued an Order which adopted most of ANR Pipeline's positions, but
required some additional refunds. No party took rehearing of the Order and it
became final. On April 13, 1998, ANR Pipeline submitted a revised reconciliation
report consistent with the FERC's Order, which report is subject to further
proceedings.
ANR Pipeline filed a general rate increase application on November 1,
1993. The FERC permitted ANR Pipeline to place increased rates into effect on
May 1, 1994, subject to refund and hearing procedures. After extensive
procedures, an administrative law judge issued an Initial Decision in January
1997 which accepted some but not all of ANR Pipeline's proposed increase. ANR
Pipeline and other parties thereafter filed exceptions regarding certain of the
findings in that Initial Decision. While those exceptions were pending review by
the FERC, ANR Pipeline filed a comprehensive settlement to resolve all issues in
the proceeding. The settlement included provisions for lower rates, refunds,
procedures to resolve certain reserved matters, as well as a proposal for a new
short-term firm service that would enable ANR Pipeline to charge higher rates
for shippers electing to purchase such new service. By order issued February 13,
1998, the FERC approved the settlement in all respects, other than the proposed
new short-term firm service, and addressed two of the three reserved matters
that the parties had requested the FERC to decide on the merits. The settlement
became effective on March 16, 1998, and on April 15, 1998, ANR Pipeline paid
refunds of $66.6 million, which included
- 11 -
<PAGE>
interest, required by the settlement. During the period the higher rates had
been in effect, ANR Pipeline estimated and recorded provisions for these
potential rate refunds, which exceeded the final refund requirements by $38.7
million. Certain proceedings related to the settlement's reserved matters are
still pending before the FERC.
On January 31, 1996, the FERC issued a "Statement of Policy and Request
for Comments" ("Policy"). Under this Policy, (i) a pipeline and a customer are
allowed to negotiate a contract which provides for rates and charges that exceed
the pipeline's posted maximum tariff rates, provided that the shipper agreeing
to such negotiated rates has the ability to elect to receive service at the
pipeline's posted maximum rate (known as a "recourse rate"), and (ii) a pipeline
must also make subsequent tariff filings each time the pipeline negotiates a
rate for service which is outside of the minimum and maximum range for the
pipeline's cost-based recourse rates. To implement this Policy, a pipeline must
make an initial tariff filing with the FERC to indicate that it intends to
contract for services under this Policy. The FERC is also considering comments
on whether this "negotiated rate" program should be extended to other terms and
conditions of pipeline transportation services.
On March 29, 1996, CIG filed with the FERC under Docket No. RP96-190 to
increase its rates by approximately $30 million annually, to realign certain
transportation services and to add tariff language that would allow CIG to enter
into "negotiated rates" (rates which could exceed CIG's "cost-based" rates) in
certain circumstances, subject to FERC policies. On April 25, 1996, the FERC
accepted the rate change filing and the transportation service realignment to
become effective October 1, 1996, subject to refund, and also accepted the
"negotiated rate" tariff provision to become effective May 1, 1996. On October
16, 1997, the FERC approved an unopposed settlement filed by CIG that resolved
all issues in the general rate case except the issues that are on appeal
relating to the "negotiated rate" tariff provisions discussed above. The final
settlement became effective on November 17, 1997, and is no longer subject to
review by the FERC or subject to any judicial review. CIG has now made refunds
of amounts collected which were in excess of the final settlement rates.
Certain parties sought judicial review of the acceptance of the
"negotiated rate" tariff provisions. That appeal has been consolidated with
other similar appeals, and the FERC has sought to have the appeal dismissed. No
action has been taken by the court on the FERC dismissal request. CIG has filed
for judicial review of the FERC's holding that pipelines which have entered into
"negotiated rate" contracts will not be allowed discount adjustments in
connection with such contracts. CIG's appeal of the "negotiated rate" provision
has been consolidated with other appeals involving the same issues, and is being
held in abeyance by the United States Court of Appeals for the D.C. Circuit.
Pending completion of judicial review, the "negotiated rate" tariff provisions
are fully effective. During 1997, CIG did not enter into any "negotiated rate"
transactions.
On May 30, 1997, Wyoming Interstate Company, Ltd. filed with the FERC to
increase its rates by approximately $5.7 million annually. On June 27, 1997, the
FERC accepted the filing effective as of December 1, 1997, subject to refund. If
the case cannot be settled, a hearing before a FERC Administrative Law Judge is
scheduled for June 2, 1998.
In July 1996, the United States Court of Appeals for the D. C. Circuit
upheld the basic structure of the FERC's Order 636 (issued in April 1992), but
remanded to the FERC, for further consideration, certain limited aspects of the
Order. In its order responding to the remand (Order 636-C, issued February 27,
1997) the FERC: (i) reaffirmed the right of pipelines to recover 100% of their
prudently incurred transition costs, but required pipelines to file within 180
days a proposal for the level of costs to be allocated to interruptible
transportation customers; and (ii) reduced from a 20-year term to a five-year
term, the "cap" to be applied to evaluation of bids for renewal of contracts on
existing volumes. ANR Pipeline and CIG have sought rehearing and clarification
of these holdings as they relate to past and future periods, and have also made
the appropriate compliance filings with the FERC. ANR Pipeline's proposal to
retain its current transition cost allocation level to interruptible service was
accepted by the FERC as part of an uncontested settlement following further
proceedings before the FERC.
CIG, ANR Pipeline, ANR Storage Company and Wyoming Interstate Company,
Ltd., subsidiaries of the Company, are regulated by the FERC. Certain of the
above regulatory matters and other regulatory issues remain unresolved among
these companies, their customers, their suppliers and the FERC. The Company has
made provisions which represent management's assessment of the ultimate
resolution of these issues. As a result, the Company anticipates that these
regulatory matters will not have a material adverse effect on its consolidated
financial position or results of operations. While the Company estimates the
provisions to be adequate to cover potential adverse rulings on these and other
issues, it cannot estimate when each of these issues will be resolved.
- 12 -
<PAGE>
Environmental Matters
The Company's operations are subject to extensive and evolving federal,
state and local environmental laws and regulations. The Company anticipates
capital expenditures of approximately $35 million in 1998 in order to comply
with such laws and regulations. The majority of the 1998 expenditures is
attributable to projects at the Company's refining, chemical and terminal
facilities. The Company currently anticipates capital expenditures for
environmental compliance for the years 1999 through 2001 of $20 to $40 million
per year. Additionally, appropriate governmental authorities may enforce the
laws and regulations with a variety of civil and criminal enforcement measures,
including monetary penalties and remediation requirements.
The Comprehensive Environmental Response, Compensation and Liability Act,
also known as "Superfund," as reauthorized, imposes liability, without regard to
fault or the legality of the original act, for disposal of a "hazardous
substance." Certain subsidiaries of the Company and a company in which Coastal
owns a 50% interest have been named as a potentially responsible party ("PRP")
in several "Superfund" waste disposal sites. At the 13 sites for which there is
sufficient information, total clean-up costs are estimated to be approximately
$295 million, and the Company estimates its pro-rata exposure, to be paid over a
period of several years, is approximately $7.4 million and has made appropriate
provisions. At seven other sites, the Environmental Protection Agency ("EPA") is
currently unable to provide the Company with an estimate of total clean-up costs
and, accordingly, the Company is unable to calculate its share of those costs.
Finally at 13 other sites, the Company has paid amounts to other PRPs or to the
EPA as its proportional share of associated clean-up costs. As to these latter
sites, the Company believes that its activities were de minimis. Additionally,
certain subsidiaries of the Company have been named as PRPs in two state sites.
At one site, the North Carolina Department of Health, Environment and Natural
Resources has estimated the total clean-up costs to be approximately $50
million, but the Company believes that the subsidiary's activities at this site
were de minimis. At the other state site, the Florida Department of
Environmental Protection has demanded reimbursement of its costs, which total
$100,000, and suitable remediation. There is not sufficient information to
estimate the remedial costs or the Company's pro-rata exposure at this site.
In Michigan, where ANR Pipeline has extensive operations, the
Environmental Response Act requires individuals (including corporations) who
have caused contamination to remediate the contamination to regulatory
standards. Owners or operators of contaminated property who did not cause the
contamination are not required to remediate the contamination, but must exercise
due care in their use of the property so that the contamination is not
exacerbated and the property does not pose a threat to human health. ANR
Pipeline estimates that its costs to comply with the Michigan regulations will
be approximately $12 million, which will be expended over a period of two to ten
years and for which appropriate provisions have been made.
On December 17, 1997, the California Regional Water Quality Control Board
issued an Administrative Compliance Order (the "Order") to Pacific Refining
Company ("Pacific"), a subsidiary of the Company, for approximately 28
violations of its Hercules Refinery's NPDES permit occurring between May 6, 1995
and September 10, 1997, when the refinery was sold to Hercules L.L.C. The Order
requires Pacific to pay $350,000 in penalties and reimburse the agency $12,000
for its staff costs.
On September 15, 1997, Javelina Company, a partnership in which Coastal
Javelina, Inc., a subsidiary of the Company, is a partner and the operator of
the facility, received a Notice of Violation ("NOV") from the EPA for alleged
violations of limits in its Clean Water Act discharge permit. Javelina Company
submitted a report detailing the measures it has implemented to abate the
alleged violations and met with the EPA to discuss why an enforcement action
should not be taken for the alleged violations. In December 1997, the EPA issued
an administrative penalty of $137,000. Javelina Company settled this matter for
less than $100,000.
On August 27, 1997, the EPA issued a NOV to Coastal Refining & Marketing,
Inc. ("CR&M"), a subsidiary of the Company, alleging that six violations of the
Clean Air Act were observed during inspections of the subsidiary's refinery in
Corpus Christi, Texas, conducted during March and April 1996. On April 29, 1998,
CR&M agreed to pay a $136,000 penalty as a complete resolution of the alleged
violations.
By letter dated April 8, 1997, the United States Department of Justice
(the "Justice Department") notified ANR Coal Company, LLC ("ANR Coal"), a
subsidiary of Coastal, that the EPA has requested the Justice Department to
bring an action against ANR Coal for alleged violations of the Clean Water Act
resulting from discharges from a mine in which
- 13 -
<PAGE>
ANR Coal had a leasehold interest in the minerals. The letter offers to settle
the matter prior to litigation for $900,000 and agreement to implement certain
injunctive relief which includes the necessary improvements to the existing
water treatment system. ANR Coal is discussing the matter with the EPA. The
Company believes that this threatened action, if an action is brought and the
allegations substantiated, could result in monetary sanctions which, while not
material to the Company and its subsidiaries, could exceed $100,000.
In April 1996, Coastal Oil & Gas Corporation ("COG"), a subsidiary of
Coastal, received a letter from the EPA Region VIII notifying it that the EPA
believes that COG's facility located in Patrick Draw, Wyoming is in violation of
certain PCB regulations promulgated pursuant to the Toxic Substances Control
Act. The EPA has offered COG an opportunity to resolve this matter without
litigation. The Company is currently having discussions with the EPA regarding
resolution of the matter. If the EPA were to initiate an action, the Company
believes that the EPA could seek penalties which, although not material, could
exceed $100,000.
In January 1996, the EPA issued a NOV to CEPOC and Eagle Point
Cogeneration Partnership ("EPCP"), in which Company subsidiaries hold a 50%
interest. The Notice alleged violations of the Clean Air Act for the failure to
obtain a Prevention of Significant Deterioration ("PSD") permit when the EPCP
was constructing the facility and for alleged violations of the facility's
operating permits. On June 25, 1997, the Justice Department sent the companies a
letter on behalf of the EPA demanding $3 million in penalties for the violations
of the operating permits. The PSD allegation was not included in the demand. The
companies have agreed to pay $300,000 as a penalty and to implement a
Supplemental Environmental Project. The EPA will withdraw, without prejudice,
the PSD allegation in the NOV. The settlement agreement is currently being
drafted.
In January 1993, the State of Texas filed suit against the Corpus Christi,
Texas refinery of CR&M, alleging failure to comply in 1992 with certain
administrative orders relating to groundwater contamination and failure to
comply with various solid and hazardous waste regulations. An agreed final
judgment was entered by the court on April 1, 1998, requiring CR&M to pay a
$500,000 penalty, spend $1.5 million on supplemental environmental projects and
perform specified clean up of the refinery's soil and groundwater.
Future information and developments will require the Company to
continually reassess the expected impact of these environmental matters.
However, the Company has evaluated its total environmental exposure based on
currently available data, including its potential joint and several liability,
and believes that compliance with all applicable laws and regulations will not
have a material adverse impact on the Company's consolidated financial position
or results of operations.
10. Subsequent Events
On April 15, 1998, the Company redeemed all 8,000,000 outstanding shares
of its $2.125 Cumulative Preferred Stock, Series H. Redemption price for the
Series H stock was $25 per share plus accrued dividends of $.182986 to April 15,
1998.
On May 13, 1998, Coastal completed a public offering of 12,000,000
Coastal-obligated mandatory redemption preferred securities through an
affiliate, Coastal Finance I, a business trust (the "Trust"), for $300 million
in cash. The Trust will hold debt securities of Coastal (the "Debt Securities")
purchased with the proceeds of the preferred securities offering. Cumulative
quarterly distributions will be paid on the preferred securities at an annual
rate of 8.375% of the liquidation amount of $25 per preferred security. The
proceeds were used to refinance borrowings incurred to finance the redemption of
the Series H Preferred Stock discussed above and to repay certain outstanding
subsidiary indebtedness. The preferred securities are mandatorily redeemable on
the maturity date, May 13, 2038, or earlier to the extent of any redemption by
Coastal of any Debt Securities. The redemption price to be paid is $25 per
preferred security, plus accrued and unpaid distributions to the date of
redemption.
- 14 -
<PAGE>
Item 2.A. Management's Discussion and Analysis of Financial Condition and
Results of Operations.
This report, including Management's Discussion and Analysis of Financial
Condition and Results of Operations, includes certain forward-looking statements
reflecting the Company's expectations and objectives in the near future;
however, many factors which may affect the actual results, including commodity
prices, market and economic conditions, industry competition and changing
regulations, are difficult to predict. Accordingly, there is no assurance that
the Company's expectations and objectives will be realized. The forward-looking
statements contained herein are intended to qualify for the safe harbor
provisions of Section 21E of the Securities Exchange Act of 1934.
The Notes to Consolidated Financial Statements contain information that is
pertinent to the following analysis.
Liquidity and Capital Resources
The Company uses the following consolidated ratios to measure liquidity
and its ability to meet future funding needs and debt service requirements.
<TABLE>
<CAPTION>
Twelve Months Ended
--------------------------------
March 31, December 31,
1998 1997
-------------- ---------------
(Unaudited)
<S> <C> <C>
Return on average common stockholders' equity.................. 13.3% 12.9%
Cash flow from operating activities to long-term debt.......... 24.6% 26.2%
Total debt to total capitalization............................. 52.6% 53.0%
Times interest earned (before tax)............................. 2.8 2.7
</TABLE>
The cash flows from operating activities to long-term debt ratio decreased
primarily due to changes in working capital.
On April 15, 1998, the Company redeemed all 8,000,000 outstanding shares
of its $2.125 Cumulative Preferred Stock, Series H. Redemption price for the
Series H stock was $25 per share plus accrued dividends of $.182986 to April 15,
1998.
On May 13, 1998, Coastal completed a public offering of 12,000,000
Coastal-obligated mandatory redemption preferred securities through an
affiliate, Coastal Finance I, a business trust (the "Trust"), for $300 million
in cash. The Trust will hold debt securities of Coastal (the "Debt Securities")
purchased with the proceeds of the preferred securities offering. Cumulative
quarterly distributions will be paid on the preferred securities at an annual
rate of 8.375% of the liquidation amount of $25 per preferred security. The
proceeds were used to refinance borrowings incurred to finance the redemption of
the Series H Preferred Stock discussed above and to repay certain outstanding
subsidiary indebtedness. The preferred securities are mandatorily redeemable on
the maturity date, May 13, 2038, or earlier to the extent of any redemption by
Coastal of any Debt Securities. The redemption price to be paid is $25 per
preferred security, plus accrued and unpaid distributions to the date of
redemption.
Financing for capital expansion, mandatory debt retirements and other
expenditures will be provided by internally generated funds, existing credit
lines, proceeds from the sale of selective non-core assets and new financings.
Funding for certain proposed projects is anticipated to be provided
through non-recourse project financings in which the projects' assets and
contracts will be pledged as collateral. Equity participation by other entities
will be considered. To the extent required, cash for equity contributions to
projects will be from general corporate funds.
- 15 -
<PAGE>
The Company continues to maintain a financial position that will enable it
to generate and obtain capital for financing needs in the foreseeable future.
Unused lines of credit at March 31, 1998 were as follows (millions of dollars):
Short-term................................... $ 776.3
Long-term*................................... 497.1
---------
$ 1,273.4
*$45.1 million of unused long-term credit lines is dedicated to a
specific use.
The AICPA has issued SOP 98-5, to be effective for periods beginning
after December 15, 1998. SOP 98-5 provides guidance on accounting for costs
incurred to open new facilities, conduct business in new territories or
otherwise commence some new operation. The application of SOP 98-5 is not
expected to have a material effect on the Company's consolidated financial
statements.
Results of Operations
The change in the Company's earnings for the three-month period ended
March 31, 1998 in comparison to the same period in 1997 is a result of the
following:
Operating Revenues. The operating revenues by segment were as follows
(millions of dollars):
<TABLE>
<CAPTION>
Three Months Ended
---------------------
March 31,
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Natural gas....................................................................... $ 416.1 $ 1,249.4
Refining, marketing and chemicals................................................. 1,353.6 1,854.0
Exploration and production........................................................ 112.4 149.0
Coal.............................................................................. 53.8 54.3
Power............................................................................. 27.8 26.0
Other............................................................................. 6.3 8.0
Adjustments and eliminations...................................................... (13.5) (134.9)
--------- ---------
$ 1,956.5 $ 3,205.8
========= =========
</TABLE>
Earnings (Loss) Before Interest and Income Taxes. The earnings (loss)
before interest and income taxes by segment was as follows (millions of
dollars):
<TABLE>
<CAPTION>
Three Months Ended
---------------------
March 31,
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
Natural gas....................................................................... $ 193.8 $ 211.0
Refining, marketing and chemicals................................................. 47.6 (47.3)
Exploration and production........................................................ 25.5 62.2
Coal ............................................................................. 2.8 12.5
Power............................................................................. 11.6 10.4
Corporate and other............................................................... (20.9) (19.2)
--------- ---------
$ 260.4 $ 229.6
========= =========
</TABLE>
Natural Gas. The decrease in operating revenues of $833.3 million can be
primarily attributed to the Company's unregulated gas marketing operations which
became a part of Engage Energy US, L.P. and Engage Energy Canada, L.P.
(collectively, "Engage Energy"). The revenues from these operations, which are
included in the Company's revenues
- 16 -
<PAGE>
through February 1997, resulted in a decrease of $833.5 million for the three
month period of 1998. Revenues for the 1997 first quarter also included a $42
million gain from an equalization payment associated with the formation of
Engage Energy.
Purchases decreased by $806.8 million in the first three months of 1998,
primarily due to the combination of the Company's unregulated gas marketing
operations noted above. Gross profit decreased by $26.5 million for the three
month period.
Earnings before interest and income taxes ("EBIT") decreased by $17.2
million as a result of the $42.0 million gain discussed above; reduced
transportation, storage and gathering revenues of $11.5 million; reduced
extracted products sales of $8.9 million and other decreases of $8.1 million
partially offset by increases of $38.7 million from a rate case settlement and
reduced depreciation, depletion and amortization of $14.6 million. Depreciation,
depletion and amortization decreased due to the revision of depreciation rates
for certain assets as discussed in Note 1 of Notes to Consolidated Financial
Statements. The other decreases are primarily due to nonrecurring provisions of
$16.1 million for environmental compliance and other matters partially offset by
an increase for interest income.
Refining, Marketing and Chemicals. Operating revenues decreased by $500.4
million in the 1998 first quarter due to decreased prices, partially offset by
increased volumes. Purchases decreased by $591.3 million, also primarily due to
lower prices, and the Company's increasing ability to use less expensive heavy
and sour crudes, resulting in a gross profit increase of $90.9 million for the
first quarter. The gross profit increase resulted from increased margins of
$77.9 million; higher sales volumes of $2.5 million; and an increase of $11.8
million from the sale, trading and exchanging of third-party products partially
offset by other decreases of $1.3 million. Included in the gross profit for the
first quarter of 1997 was an inventory loss of $60.0 million which resulted from
falling product and crude oil prices.
The EBIT increase of $94.9 million resulted from the increased gross profit
of $90.9 million and decreased operating and general expenses of $8.9 million
partially offset by reduced earnings from equity investments of $4.1 million and
increased depreciation, depletion and amortization of $.8 million. Operating and
general expenses decreased as a result of lower fuel and other costs at the
refineries and reduced expenses due to the elimination of marginal activities,
primarily in the Northeast.
Exploration and Production. Operating revenues decreased by $36.6 million
in the 1998 first quarter as a result of lower prices being partially offset by
increased volumes. The EBIT decrease of $36.7 million results from lower prices
of $44.0 million and increased depreciation, depletion and amortization of $4.5
million being partially offset by increased volumes of $5.1 million, reduced
operating and general expenses of $3.1 million and other changes of $3.6
million. Depreciation, depletion and amortization increased as a result of a
higher rate and increased production volumes.
Coal. The operating revenues decrease of $.5 million for the 1998 three
month period results from lower prices being partially offset by increased
volumes. EBIT decreased by $9.7 million due to the revenue decrease of $.5
million, a non-recurring favorable resolution of a contingency in the first
quarter of 1997 for $9.0 million and other decreases of $.2 million.
Power. Operating revenues increased by $1.8 million in the 1998 first
quarter due primarily to increased operating levels for the El Salvador
operations. The EBIT increase of $1.2 million results from the $1.8 million
revenue increase and increased earnings from equity investments of $3.4 million
partially offset by increased operating expenses of $3.9 million and higher
depreciation, depletion and amortization expense of $.1 million. The operating
expense increase is a result of increased El Salvador operating levels and
increased administrative and development costs related to joint venture
projects.
Corporate and Other. The EBIT for these operations, which include equity
income from trucking, real estate activities and corporate income and expense
not allocated to the operating segments, decreased as a result of the sale of
certain real estate properties in 1997 and reduced earnings from equity
investments for the trucking operations.
Interest and Debt Expense. Interest and debt expense decreased by $3.9
million due primarily to reduced rates on variable rate debt.
- 17 -
<PAGE>
Taxes on Income. Federal income taxes increased by $10.2 million in the
1998 period as a result of increased earnings before taxes. State income taxes
increased by $2.9 million and foreign income taxes decreased by $.1 million.
Extraordinary Item. The 1997 extraordinary item, net of income taxes,
resulted from the early retirement of debt.
Environmental Matters
The Company's operations are subject to extensive and evolving federal,
state and local environmental laws and regulations. The Company anticipates
capital expenditures of approximately $35 million in 1998 in order to comply
with such laws and regulations. The majority of the 1998 expenditures is
attributable to projects at the Company's refining, chemical and terminal
facilities. The Company currently anticipates capital expenditures for
environmental compliance for the years 1999 through 2001 of $20 to $40 million
per year. Additionally, appropriate governmental authorities may enforce the
laws and regulations with a variety of civil and criminal enforcement measures,
including monetary penalties and remediation requirements.
The Comprehensive Environmental Response, Compensation and Liability Act,
also known as "Superfund," as reauthorized, imposes liability, without regard to
fault or the legality of the original act, for disposal of a "hazardous
substance." Certain subsidiaries of the Company and a company in which Coastal
owns a 50% interest have been named as a potentially responsible party ("PRP")
in several "Superfund" waste disposal sites. At the 13 sites for which there is
sufficient information, total clean-up costs are estimated to be approximately
$295 million, and the Company estimates its pro-rata exposure, to be paid over a
period of several years, is approximately $7.4 million and has made appropriate
provisions. At seven other sites, the Environmental Protection Agency ("EPA") is
currently unable to provide the Company with an estimate of total clean-up costs
and, accordingly, the Company is unable to calculate its share of those costs.
Finally at 13 other sites, the Company has paid amounts to other PRPs or to the
EPA as its proportional share of associated clean-up costs. As to these latter
sites, the Company believes that its activities were de minimis. Additionally,
certain subsidiaries of the Company have been named as PRPs in two state sites.
At one site, the North Carolina Department of Health, Environment and Natural
Resources has estimated the total clean-up costs to be approximately $50
million, but the Company believes that the subsidiary's activities at this site
were de minimis. At the other state site, the Florida Department of
Environmental Protection has demanded reimbursement of its costs, which total
$100,000, and suitable remediation. There is not sufficient information to
estimate the remedial costs or the Company's pro-rata exposure at this site.
Future information and developments will require the Company to
continually reassess the expected impact of these environmental matters.
However, the Company has evaluated its total environmental exposure based on
currently available data, including its potential joint and several liability,
and believes that compliance with all applicable laws and regulations will not
have a material adverse impact on the Company's consolidated financial position
or results of operations.
Item 2.B. Other Development.
An affiliate of ANR Pipeline owns a one-third general partnership interest
in the proposed Independence Pipeline project. The proposed Independence
Pipeline project consists of the construction of 400 miles of 36-inch diameter
pipe, with an annual designed delivery capacity of 917 MMcf per day. The
in-service date of the Independence Pipeline project has been revised to
November 2000, subject to receipt of satisfactory regulatory approvals.
- 18 -
<PAGE>
PART II
OTHER INFORMATION
Item 1. Legal Proceedings.
The information required hereunder is incorporated by reference into
Part II of this Report from Note 9 of the Notes to Consolidated Financial
Statements set forth in Part I of this Report and from Item 2.A., "Management's
Discussion and Analysis of Financial Condition and Results of Operations -
Environmental Matters" set forth in Part I of this Report.
Item 2. Changes in Securities.
None.
Item 3. Defaults Upon Senior Securities.
None.
Item 4. Submission of Matters to a Vote of Security Holders.
None.
Item 5. Other Information.
None.
Item 6. Exhibits and Reports on Form 8-K.
(a) Exhibits.
11 - Statement re Computation of Per Share Earnings.
27 - Financial Data Schedule.
(b) Reports on Form 8-K.
No Reports on Form 8-K were filed during the quarter ended March
31, 1998.
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934,
the Registrant has duly caused this Report to be signed on its behalf by the
undersigned thereunto duly authorized.
THE COASTAL CORPORATION
(Registrant)
COBY C. HESSE
Date: May 14, 1998 By: -------------------------------------
Coby C. Hesse
Executive Vice President
and Principal Accounting Officer
(As Authorized Officer and
Chief Accounting Officer)
- 19 -
<PAGE>
INDEX TO EXHIBITS
Exhibit
Number Description
- ------- -----------------------------------------------------------------
11 Statement Re Computation of Per Share Earnings
27 Financial Data Schedule
- 20 -
<PAGE>
EXHIBIT 11
<TABLE>
THE COASTAL CORPORATION AND SUBSIDIARIES
STATEMENT RE COMPUTATION OF PER SHARE EARNINGS
(Millions of Dollars, Except Per Share Amounts,
and Thousands of Shares)
<CAPTION>
Three Months Ended
March 31,
---------------------
1998 1997
--------- ---------
(Unaudited)
<S> <C> <C>
BASIC EARNINGS PER SHARE
Net earnings......................................................................... $ 122.9 $ 10.6
Dividends on preferred stock......................................................... 4.3 4.3
--------- ---------
Net earnings available to common stockholders........................................ $ 118.6 $ 6.3
========= =========
Average number of common shares outstanding............................................. 211,871 211,209
Average number of Class A common shares outstanding..................................... 365 381
--------- ---------
212,236 211,590
========= =========
Basic earnings per share:
Before extraordinary item............................................................ $ .56 $ .46
Extraordinary item................................................................... - (.43)
--------- ---------
Net basic earnings per share......................................................... $ .56 $ .03
========= =========
DILUTED EARNINGS PER SHARE
Net earnings used in calculating basic earnings per share............................ $ 118.6 $ 6.3
Dividends applicable to dilutive preferred stock:
Series A.......................................................................... - -
Series B.......................................................................... - -
Series C.......................................................................... .1 .1
--------- ---------
Income available to common shareholders plus
assumed conversions............................................................... $ 118.7 $ 6.4
========= =========
Average number of shares used in calculating basic earnings
per share............................................................................ 212,236 211,590
Effect of dilutive securities:
Options.............................................................................. 2,116 1,554
Series A, B and C preferred stock.................................................... 1,349 1,447
--------- ---------
215,701 214,591
========= =========
Diluted earnings per share:
Before extraordinary item............................................................ $ .55 $ .45
Extraordinary item................................................................... - (.42)
--------- ---------
Net basic earnings per share......................................................... $ .55 $ .03
========= =========
</TABLE>
------------------------------------
Convertible securities and options are not considered in the calculations if
the effect of the conversion is anti-dilutive.
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND> THE SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION
EXTRACTED FROM THE COASTAL CORPORATION FORM 10-Q
QUARTERLY REPORT FOR THE PERIOD ENDED MARCH 31, 1998
AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH
FINANCIAL STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000,000
<S> <C>
<PERIOD-TYPE> 3-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> MAR-31-1998
<CASH> 20
<SECURITIES> 0
<RECEIVABLES> 1,169
<ALLOWANCES> 0
<INVENTORY> 544
<CURRENT-ASSETS> 1,987
<PP&E> 10,927
<DEPRECIATION> 3,618
<TOTAL-ASSETS> 11,309
<CURRENT-LIABILITIES> 1,966
<BONDS> 3,759
<COMMON> 72
100
3
<OTHER-SE> 3,318
<TOTAL-LIABILITY-AND-EQUITY> 11,309
<SALES> 1,957
<TOTAL-REVENUES> 1,976
<CGS> 1,186
<TOTAL-COSTS> 1,716
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 75
<INCOME-PRETAX> 185
<INCOME-TAX> 62
<INCOME-CONTINUING> 123
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 123
<EPS-PRIMARY> .56
<EPS-DILUTED> .55
</TABLE>
