Page 1 of 33
FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
Quarterly Report Under Section 13 or 15(d)
of the Securities Exchange Act of 1934
For the Quarter Ended March 31, 1997
Commission File Number 1-3751
NorAm Energy Corp.
(Exact name of registrant as specified in its charter)
DELAWARE 72-0120530
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
NorAm Energy Corp.
1600 Smith Street, 32nd Floor
Houston, Texas 77002
(Address of principal executive offices)
(713) 654-5699
(Registrant's telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days.
Yes x No
Outstanding Common Stock, $.625 Par Value
at May 9, 1997 - 138,236,643
Exhibit Index Appears on Page 32
<PAGE>
INDEX
Page
Part I. Financial Information 3
Item 1. Financial Statements
Consolidated Balance Sheet - March 31, 1997 and 1996
and December 31, 1996 4
Consolidated Statement of Income - Three Months Ended
March 31, 1997 and 1996 6
Statement of Consolidated Cash Flows - Three Months Ended
March 31, 1997 and 1996 7
Notes to Consolidated Financial Statements 8
Item 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations 13
Part II. Other Information
Item 1. Legal Proceedings 32
Item 6. Exhibits and Reports on Form 8-K 32
Signature 33
<PAGE>
Part I. Financial Information
Item 1. Financial Statements
The consolidated financial statements of NorAm Energy Corp. and
Subsidiaries ("the Company") included herein have been prepared, without audit,
pursuant to the rules and regulations of the Securities and Exchange Commission.
Certain information and notes normally included in financial statements prepared
in accordance with generally accepted accounting principles have been condensed
or omitted pursuant to such rules and regulations, although the Company believes
that the disclosures are adequate to make the information presented not
misleading. It is suggested that these financial statements be read in
conjunction with the financial statements and the notes thereto included in the
Company's Report on Form 10-K for the year ended December 31, 1996.
<PAGE>
<TABLE>
<CAPTION>
NorAm Energy Corp. and Subsidiaries
CONSOLIDATED BALANCE SHEET
(in thousands of dollars)
(unaudited)
ASSETS March 31 December 31 March 31
- ------
1997 1996 1996
------------------ ------------------- -------------------
<S> <C> <C> <C>
Property, Plant and Equipment
Natural Gas Distribution $ 2,170,887 $ 2,158,013 $ 2,079,057
Interstate Pipelines 1,684,073 1,685,959 1,672,136
Energy Marketing and Gathering 258,795 252,509 229,596
Other 21,058 20,150 18,138
------------------ ------------------- -------------------
4,134,813 4,116,631 3,998,927
Less: Accumulated depreciation and amortization 1,700,136 1,675,576 1,595,742
------------------ ------------------- -------------------
2,434,677 2,441,055 2,403,185
Investments and Other Assets
Goodwill, net 463,392 466,938 477,578
Prepaid pension asset 49,700 45,390 48,849
Investment in Itron, Inc. 28,548 26,670 67,239
Regulatory asset for environmental costs 37,019 39,152 45,650
Gas purchased in advance of delivery 32,638 34,895 34,708
Other 16,522 32,200 21,139
------------------ ------------------- -------------------
627,819 645,245 695,163
Current Assets
Cash and cash equivalents 34,599 27,981 22,774
Accounts and notes receivable, principally
customer (Note F) 752,849 696,982 467,701
Deferred income taxes 21,266 10,495 14,084
Inventories
Gas in underground storage 24,912 70,651 8,233
Materials and supplies 30,777 30,595 29,701
Other 688 631 371
Deferred gas cost (6,390) 231 (16,866)
Gas purchased in advance of delivery 6,200 6,200 6,200
Other current assets 8,032 14,561 9,749
------------------ ------------------- -------------------
872,933 858,327 541,947
Deferred Charges 55,501 72,850 47,461
------------------ ------------------- -------------------
TOTAL ASSETS $ 3,990,930 $ 4,017,477 $ 3,687,756
================== =================== ===================
</TABLE>
The Notes to Consolidated Financial Statements are an
integral part of this statement.
<PAGE>
<TABLE>
<CAPTION>
NorAm Energy Corp. and Subsidiaries
CONSOLIDATED BALANCE SHEET
(in thousands of dollars)
(unaudited)
LIABILITIES AND STOCKHOLDERS' EQUITY March 31 December 31 March 31
- ------------------------------------
1997 1996 1996
------------------- ------------------ -----------------
<S> <C> <C> <C>
Stockholders' Equity
Preferred stock - - $ 130,000
Common stock $ 86,393 $ 86,193 78,281
Paid-in capital 1,004,810 1,001,053 884,152
Accumulated deficit (227,687) (286,703) (286,683)
Unrealized gain on investment, net of tax 1,204 5 25,844
------------------- ------------------ -----------------
Total Stockholders' Equity 864,720 800,548 831,594
Company-Obligated Mandatorily Redeemable
Convertible Preferred Securities of Subsidiary
Trust Holding Solely $177.8 Million Principal
Amount of 6.25% Convertible Subordinated
Debentures Due 2026 of NorAm Energy Corp. 164,427 167,768 -
Long-Term Debt, Less Current Maturities 1,047,469 1,054,221 1,467,524
Current Liabilities
Current maturities of long-term debt 278,000 277,000 48,750
Notes payable to banks 87,000 115,000 -
Receivables facility (Note F) 225,000 - -
Accounts payable, principally trade 478,348 762,164 482,588
Income taxes payable 44,757 11,684 45,148
Interest payable 30,772 31,928 30,876
General taxes 49,941 51,082 48,149
Customers' deposits 35,841 35,711 35,611
Other current liabilities 76,424 113,628 91,514
------------------- ------------------ -----------------
1,306,083 1,398,197 782,636
Other Liabilities and Deferred Credits
Accumulated deferred income taxes 339,363 320,506 316,479
Estimated environmental remediation costs 37,019 39,152 45,650
Payable under capacity lease agreement 41,000 41,000 41,000
Supplemental retirement and deferred compensation 40,392 39,640 39,079
Estimated obligations under indemnification
provisions of sales agreements 22,018 29,098 34,013
Refundable excess deferred income taxes 17,658 17,946 19,885
Other 110,781 109,401 109,896
------------------- ------------------ -----------------
608,231 596,743 606,002
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $ 3,990,930 $ 4,017,477 $ 3,687,756
=================== ================== =================
</TABLE>
The Notes to Consolidated Financial Statements are an
integral part of this statement.
<PAGE>
<TABLE>
<CAPTION>
NorAm Energy Corp. and Subsidiaries
CONSOLIDATED STATEMENT OF INCOME
(in thousands of dollars except per share amounts)
(unaudited)
Three Months
Ended March 31
-------------------------------
1997 1996
--------------- --------------
<S> <C> <C>
Operating Revenues $ 1,924,182 $ 1,417,663
Operating Expenses
Cost of natural gas purchased, net 1,579,178 1,027,542
Operating, maintenance, cost of sales & other 127,640 150,849
Depreciation and amortization 35,988 35,710
Taxes other than income taxes 36,155 34,636
Early retirement and severance (Note C) - 22,344
--------------- --------------
1,778,961 1,271,081
Operating Income 145,221 146,582
Other (Income) and Deductions
Interest expense, net (Note F) 35,472 36,170
Dividend requirement on preferred securities
of subsidiary trust 2,705 -
Other, net (Note C) (6,309) 3,427
--------------- --------------
31,868 39,597
Income Before Income Taxes 113,353 106,985
Provision for Income Taxes 44,943 45,788
--------------- --------------
Income Before Extraordinary Item 68,410 61,197
Extraordinary gain (loss) on early
retirement of debt, less taxes 237 (278)
--------------- --------------
Net Income 68,647 60,919
Preferred dividend requirement - 1,950
--------------- --------------
Earnings Available to Common Stock $ 68,647 $ 58,969
=============== ==============
Per Share Data:
Primary:
Before extraordinary item $ 0.50 $ 0.47
Extraordinary item, less taxes 0.00 0.00
--------------- --------------
Earnings per Common Share $ 0.50 $ 0.47
=============== ==============
Fully Diluted:
Before extraordinary item $ 0.46 $ 0.47
Extraordinary item, less taxes 0.00 0.00
--------------- --------------
Earnings per Common Share $ 0.46 $ 0.47
=============== ==============
Average Common Shares
Outstanding (in thousands)
Primary 137,956 124,991
Fully diluted 152,183 124,991
Cash Dividends per Common Share $ 0.07 $ 0.07
</TABLE>
The Notes to Consolidated Financial Statements are an
integral part of this statement.
<PAGE>
<TABLE>
<CAPTION>
NorAm Energy Corp. and Subsidiaries
STATEMENT OF CONSOLIDATED CASH FLOWS
Increase(Decrease) in Cash and Cash Equivalents (1)
(in thousands of dollars)
(unaudited)
Three Months
Ended March 31
------------------------------------
1997 1996
---------------- ----------------
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $ 68,647 $ 60,919
Adjustments to reconcile net income to cash provided
by operating activities:
Depreciation and amortization 35,988 35,710
Early retirement and severance, less cash costs (Note C) - 12,941
Deferred income taxes 7,360 6,541
Extraordinary (gain) loss, less taxes (237) 278
Other 905 885
Changes in certain assets and liabilities, net of noncash transactions:
Accounts and notes receivable, principally customer (Note F) 179,133 (131,922)
Inventories 45,500 48,677
Deferred gas costs 6,621 29,885
Other current assets 6,529 15,747
Accounts payable, principally trade (249,848) 18,850
Income taxes payable 33,073 39,811
Interest payable (1,156) (7,854)
General taxes (1,141) (171)
Customers' deposits 130 (40)
Other current liabilities (37,204) (11,631)
Recoveries under gas contract disputes 3,300 7,200
---------------- ----------------
Net cash provided by operating activities 97,600 125,826
---------------- ----------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (26,700) (25,200)
Other, net 4,987 2,447
---------------- ----------------
Net cash used in investing activities (21,713) (22,753)
---------------- ----------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Retirements and reacquisitions of long-term debt (5,515) (77,678)
Increase (decrease) in overdrafts (16,123) 1,968
Other interim debt repayments (28,000) (10,000)
Decrease in receivables facility (Note F) (10,000) -
Issuance of common stock under Direct Stock Purchase Plan - 2,761
Common and preferred stock dividends (Note E) (9,631) (10,661)
---------------- ----------------
Net cash used in financing activities (69,269) (93,610)
---------------- ----------------
Net increase in cash and cash equivalents 6,618 9,463
Cash and cash equivalents - beginning of period 27,981 13,311
---------------- ----------------
Cash and cash equivalents - end of period $ 34,599 $ 22,774
================ ================
(1) All highly liquid investments purchased with an original maturity
of three months or less are considered to be cash equivalents.
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash interest payments, net of capitalized interest $ 36,120 $ 43,891
Net cash income tax payments $ 3,770 $ 94
</TABLE>
The Notes to Consolidated Financial Statements are an
integral part of this statement.
<PAGE>
================================================================================
NorAm Energy Corp. and Subsidiaries
================================================================================
Notes to Consolidated Financial Statements
(unaudited)
A. In the opinion of Management, all adjustments (consisting solely of normal
recurring accruals, except as explicitly described herein) necessary for a
fair presentation of results of operations for the periods presented have
been included in the accompanying consolidated financial statements.
Because of the seasonal nature of the Company's operations, among other
factors, the results of operations for the periods presented are not
necessarily indicative of the results that will be achieved in an entire
year. The preparation of financial statements requires Management to make
estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date
of the financial statements and the reported amounts of revenues and
expenses during each reporting period. Actual results could differ from
those estimates. In the accompanying consolidated financial statements,
certain prior period amounts have been reclassified to conform to the
current presentation.
B. On August 11, 1996, the Company entered into an Agreement and Plan of
Merger (the "Merger Agreement") with Houston Industries Incorporated
("Houston Industries" or "HI"), Houston Lighting & Power Company ("HL&P")
and a newly formed Delaware subsidiary of Houston Industries ("HI Merger,
Inc."). Under the Merger Agreement, the Company would merge with and into
HI Merger, Inc. and would become a wholly-owned subsidiary of HII (as
defined following). Houston Industries would merge with and into HL&P,
which would be renamed Houston Industries Incorporated ("HII") (the term
"Transaction" refers to the business combination between Houston Industries
and the Company). Consideration for the purchase of the Company's common
stock would be a combination of cash and shares of HI common stock, valued
at approximately $3.8 billion, consisting of approximately $2.4 billion for
the Company's common stock and equivalents and approximately $1.4 billion
in assumption of the Company's debt. Additional information concerning the
Merger Agreement is contained in the Joint Proxy Statement/Prospectus of
Houston Industries, HL&P and the Company dated October 29, 1996 ("the
Proxy/Prospectus").
The Merger Agreement was approved and adopted at Special Meetings of
Houston Industries' and the Company's stockholders held on December 17,
1996. The Company and HI proceeded to obtain required state and municipal
regulatory approvals, all of which have been obtained, and to request an
exemption from the Securities and Exchange Commission ("the SEC") which
would allow the Transaction to take place under its preferred structure
without subjecting post-merger HII to the requirements of the Public
Utility Holding Company Act. It is HI's and the Company's intention to
defer the closing of the Transaction until the SEC issues its ruling on the
exemption request although, as set forth in the Proxy/Prospectus, there are
two alternative structures, one of which would not require SEC approval.
Adoption of either of these structures, however, would require that the
Company and HI make new filings to obtain the various state and municipal
regulatory approvals.
In early February 1997, the Federal Energy Regulatory Commission ("the
FERC" or "the Commission") issued an order ("the Initial Order") advising
the Company that the Transaction "...may require Commission approval
pursuant to section 203 of the FPA" (the "FPA" refers to the Federal Power
Act), and directing the Company to file a response within 30 days of the
Initial Order either "...(1) providing arguments as to why the transaction
does not require Commission authorization under section 203 or (2) an
application under section 203". In early March 1997, the Company filed a
response to the Initial Order stating its view that the FERC does not have
jurisdiction over the Transaction. Although such response disclaimed any
FERC jurisdiction over the Transaction, it also indicated that one option
being considered was to file an application with the FERC for approval of
the Transaction in anticipation of an expedited review under the FERC's
newly-issued merger policy guidelines. On March 27, 1997, the Company filed
an application under section 203 of the FPA (Docket No. EC97-24-000)
seeking FERC approval of the Transaction, although continuing to assert its
position that such approval is not required. On April 30, 1997, the FERC
issued an additional order ("the Jurisdiction Order") in which it found
that "...the proposed merger involves the disposition of NorAm's [NorAm
Energy Services] jurisdictional facilities via a change of control of those
facilities and, thus, falls within the jurisdiction of the Commission under
section 203 of the FPA."
The Company continues to believe that the Transaction will be completed as
contemplated although, in light of the pending regulatory issues as set
forth preceding, the Company cannot predict with any degree of certainty
when the Transaction will be consummated.
<PAGE>
C. Following are components of and information concerning certain line items
from the accompanying consolidated financial statements:
Operating Revenues and Cost of Natural Gas Purchased, Net
The significant increases in "Operating Revenues" and "Cost of natural gas
purchased, net" in the Company's Consolidated Statement of Income from the
first quarter of 1996 to the first quarter of 1997 are principally due to
the increased level of the Company's energy marketing activities, see
"Wholesale Energy Marketing" and "Retail Energy Marketing" under "Material
Changes in the Results of Continuing Operations" included with "Management
Analysis" in the Company's 1996 Report on Form 10-K and "Energy Marketing
and Gathering" under "Material Changes in the Results of Operations"
included with "Management's Discussion and Analysis of Financial Condition
and Results of Operations" elsewhere herein.
Early Retirement and Severance
During the first quarter of 1996, the Company instituted a reorganization
plan affecting its NorAm Gas Transmission Company ("NGT") and Mississippi
River Transmission Corporation ("MRT") subsidiaries, pursuant to which a
total of approximately 275 positions were eliminated, resulting in expense
for severance payments and enhanced retirement benefits. Also during the
first quarter of 1996, (1) the Company's Entex division instituted an early
retirement program which was accepted by approximately 100 employees and
(2) the Company's Minnegasco division reorganized certain functions,
resulting in the elimination of approximately 25 positions. Collectively,
these programs resulted in a pre-tax charge of approximately $22.3 million
(approximately $13.4 million or $0.10 per share after tax), which pre-tax
amount is reported in the accompanying Statement of Consolidated Income as
"Early retirement and severance".
Other, Net
"Other, net" for the three months ended March 31, 1997 includes the impact
of the close-out of certain interest rate swaps, and the comparison of
"Other, net" between periods is affected by the adoption of a new
accounting standard, see Note F.
Provision for Income Taxes
"Provision for Income Taxes" in the Company's Consolidated Statement of
Income includes the following:
<TABLE>
<CAPTION>
Three Months
Ended March 31
-------------------------------
1997 1996
------------- --------------
(millions of dollars)
<S> <C> <C>
Federal
Current $ 34.8 $ 33.3
Deferred 6.9 4.4
Investment tax credit (0.2) (0.1)
State
Current 2.9 6.1
Deferred 0.5 2.1
============= ==============
$ 44.9 $ 45.8
============= ==============
</TABLE>
Investments and Other Assets
At May 6, 1997, the Company's investment in Itron, Inc. common stock had
increased to $35.1 million and its unrealized gain to $5.4 million (net of
tax of $3.1 million). As discussed in the Company's 1996 Report on Form
10-K, the market for this security has limited liquidity.
Inventories
The decrease in "Gas in underground storage" from December 31, 1996 to
March 31, 1997 is principally a normal seasonal fluctuation.
<PAGE>
<TABLE>
<CAPTION>
Retirements and Reacquisitions of Long-Term Debt
Three Months
Ended March 31
--------------------------------
1997 1996
-------------- --------------
(millions of dollars)
<S> <C> <C>
Reacquisition of 6% Debentures Due 2012 $ 5.7 -
Reacquisition of 9.875% Series Due 2018 - $ 7.4
Retirement, at maturity, of Medium-Term Notes,
weighted average interest rate of 9.27% - 70.0
Net loss (gain) on reacquisition of debt, less taxes (0.2) 0.3
-------------- --------------
$ 5.5 $ 77.7
============== ==============
</TABLE>
D. As further discussed in the Company's 1996 Report on Form 10-K, in early
1997, the Company learned that four consortiums ("the Consortiums"), each
of which included the Company, were the successful bidders for the right to
build and operate natural gas distribution facilities in each of four
defined service areas ("the Concessions") within Colombia. Contracts, which
extend through the year 2014 and grant the exclusive right to distribute
gas to consumers of less than 500 Mcf per day (and the right to compete for
other customers), were awarded in April 1997.
E. Primary earnings per share is computed using the weighted average number of
shares of the Company's Common Stock ("Common Stock") actually outstanding
during each period presented. Outstanding options for purchase of Common
Stock, the Company's only "common stock equivalent" as that term is defined
in the applicable authoritative accounting literature, have been excluded
due to either (1) the fact that the options would have been anti-dilutive
if exercised or (2) the immaterial impact which would result from the
exercise of those options which are currently exercisable and would be
dilutive if exercised. Fully diluted earnings per share, in addition to the
actual weighted average common shares outstanding, assumes the conversion,
beginning with its issuance date of June 17, 1996, of the 3,450,000 shares
of the Company-Obligated Mandatorily Redeemable Convertible Preferred
Securities of Subsidiary Trust Holding Solely $177.8 Million Principal
Amount of 6.25% Convertible Subordinated Debentures Due 2026 of NorAm
Energy Corp. ("the Trust Preferred") at a conversion rate of 4.1237 shares
of Common Stock for each share of the Trust Preferred (resulting in the
assumed issuance of a total of 14,226,765 shares of Common Stock), and
reflects the increase in earnings from the cessation of the dividends on
the Trust Preferred (net of the related tax benefit) which would result
from such assumed conversion. For the three months ended March 31, 1997,
this assumed earnings increase was approximately $1.6 million, net of
related tax benefit of approximately $1.1 million. The Company's 6%
Convertible Subordinated Debentures due 2012 and the Company's $3.00 Series
A Preferred Stock (prior to its June 1996 exchange), due to their exchange
rates, are anti-dilutive and are therefore excluded from all earnings per
share calculations. During the periods in which the Company's $3.00
Convertible Exchangeable Preferred Stock, Series A was outstanding,
earnings per share from continuing operations is calculated after reduction
for the preferred stock dividend requirement associated with such security.
In February 1997, the Financial Accounting Standards Board issued Statement
of Financial Accounting Standards No. 128, "Earnings per Share" ("SFAS
128"), which is required to be implemented for fiscal years ending after
December 15, 1997 and earlier application is not permitted. SFAS 128
replaces the current "primary earnings per share" ("primary EPS") and
"fully diluted earnings per share" ("fully diluted EPS") with "basic
earnings per share" ("basic EPS") and "diluted earnings per share"
("diluted EPS"). Unlike the calculation of primary EPS which includes, in
its denominator, the sum of (1) actual weighted shares outstanding and (2)
"common stock equivalents" as that term is defined in the applicable
authoritative literature, basic EPS is calculated using only the actual
weighted average shares outstanding during the relevant periods. Diluted
EPS is very similar to fully diluted EPS, differing only in technical ways
which do not currently affect the Company.
F. As further discussed in the Company's 1996 Report on Form 10-K, under an
August 1996 agreement ("the Receivables Facility"), the Company transfers
(to a third party) an undivided interest in a pool of accounts receivable
with limited recourse and subject to a floating interest rate provision.
The maximum amount allowed under the Receivables Facility was $235.0
million until late April 1997, at which time the Company was allowed to
increase the maximum to $300 million, pending completion of a formal
amendment. The total interest in the Company's receivables transferred
pursuant to the Receivables Facility but not yet collected was
approximately $225.0 million, $235.0 million and $193.3 million at March
31, 1997, December 31, 1996 and March 31, 1996, respectively. "Interest
expense, net" for the three months ended March 31, 1997 includes
approximately $3.0 million of costs associated with the Receivables
Facility, while a similar amount is included in "Other, net" in the
corresponding period of 1996, see the discussion following. At March 31,
1997, approximately $32.7 million of the Company's receivables were
collateral for amounts received pursuant to the Receivables Facility and,
at April 30, 1997, an interest in $300.0 million of the Company's
receivables had been transferred.
As discussed in the Company's 1996 Report on Form 10-K, in March 1997, the
Company closed out the $200.0 million of swaps which had been serving as
hedges of its anticipated April 1997 debt refinancing, receiving cash
proceeds of approximately $8.7 million. As discussed in the Company's 1996
Report on Form 10-K, based on the Company's expected utilization of a
smaller, shorter-term refinancing vehicle, approximately $1.0 million of
such proceeds will serve to reduce the effective interest rate on the debt
to be issued, and the balance was credited to earnings in March 1997,
reported as a component of "Other, net" in the Company's Statement of
Consolidated Income.
As further described in the Company's 1996 Report of Form 10-K, the Company
adopted Statement of Financial Accounting Standards No. 125, "Accounting
for Transfers and Servicing of Financial Assets and Extinguishment of
Liabilities" ("SFAS 125") effective as of January 1, 1997 (SFAS 125 does
not allow retroactive application). Therefore, for periods prior to January
1, 1997, (1) amounts transferred pursuant to the Receivables Facility are
included with "Cash Flows From Operating Activities" in the Company's
Statement of Consolidated Cash Flows, (2) receivables transferred pursuant
to the Receivables Facility are deducted from "Accounts and notes
receivable, principally customer" in the Company's Consolidated Balance
Sheet and (3) the costs associated with utilization of the Receivables
Facility are reported as "Loss on sale of accounts receivable", a component
of "Other, net", included under "Other (Income) and Deductions" in the
Company's Statement of Consolidated Income. Subsequent to January 1, 1997,
(1) amounts transferred pursuant to the Receivables Facility are included
with "Cash Flows from Financing Activities" in the Company's Statement of
Consolidated Cash Flows, (2) amounts received pursuant to the Receivables
Facility are not deducted from "Accounts and notes receivable, principally
customer" in the Company's Consolidated Balance Sheet but, rather, such
amounts are reported as short-term debt, and (3) the costs associated with
utilization of the Receivables Facility are included with "Interest
expense, net" in the Company's Statement of Consolidated Income.
Therefore, due to the different balance sheet classification of amounts
transferred pursuant to the Receivables Facility as described preceding,
the cash flow impacts reported as "Accounts and notes receivable,
principally customer" and "Decrease in receivables facility" in the
Company's Statement of Consolidated Cash Flows for the three months ended
March 31, 1997 are not equal to the changes in the associated balance sheet
captions from December 31, 1996 to March 31, 1997. Instead, such impacts
have been calculated as if the change in balance sheet classification had
been in effect at the beginning of the period, resulting in cash flow
impacts which are not affected by the change in classification.
G. As more fully described in the Company's 1996 Report on Form 10-K, the
Company is currently working with the Minnesota Pollution Control Agency
regarding the remediation of several sites on which gas was manufactured
from the late 1800's to approximately 1960. The Company has made an accrual
for its estimate of the costs of remediation (undiscounted and without
regard to potential third-party recoveries) and, based upon discussions to
date and prior decisions by regulators in the relevant jurisdictions, the
Company continues to believe that it will be allowed substantial recovery
of these costs through its regulated rates.
In addition, the Company has identified sites with possible mercury
contamination based on the type of facilities located on these sites. The
Company has not confirmed the existence of contamination at these sites,
nor has any federal, state or local governmental agency imposed on the
Company an obligation to investigate or remediate existing or potential
mercury contamination. To the extent that any compliance costs are
ultimately identified and quantified, the Company will provide an
appropriate accrual and, to the extent justified based on the circumstances
within each of the Company's regulatory jurisdictions, set up regulatory
assets in anticipation of recovery through the ratemaking process.
On October 24, 1994, the United States Environmental Protection Agency
advised MRT that it had been named a potentially responsible party under
federal law with respect to a landfill site in West Memphis, Arkansas, see
Note H.
On December 18, 1995, the Louisiana Department of Environmental Quality
advised the Company that it had been named a potentially responsible party
under state law with respect to a hazardous substance site in Shreveport,
Louisiana, see Note H.
While the nature of environmental contingencies makes complete evaluation
impractical, the Company is currently aware of no other environmental
matter which could reasonably be expected to have a material impact on its
results of operations, financial position or cash flows.
H. On August 14, 1996, an action styled Shaw vs. NorAm Energy Corp., et al.
was filed in the District Court of Harris County, Texas by a purported
NorAm stockholder against the Company, certain of its officers and
directors and Houston Industries to enjoin the merger between the Company
and Houston Industries (see Note B) or to rescind such merger and/or to
recover damages in the event that the Transaction is consummated. The
complaint alleges, among other things, that the merger consideration is
inadequate, the Company's Board of Directors breached its fiduciary duties
and that Houston Industries aided and abetted such breaches of fiduciary
duties. In addition, the plaintiff seeks certification as a class action.
The Company believes that the claims are without merit and intends to
vigorously defend against the lawsuit. Management believes that the effect
on the Company's results of operations, financial position or cash flows,
if any, from the disposition of this matter will not be material.
On October 24, 1994, the United States Environmental Protection Agency
advised MRT, a wholly-owned subsidiary of the Company, that MRT, together
with a number of other companies, had been named under federal law as a
potentially responsible party for a landfill site in West Memphis, Arkansas
and may be required to share in the cost of remediation of this site.
However, considering the information currently known about the site and the
involvement of MRT, the Company does not believe that this matter will have
a material adverse effect on the financial position, results of operations
or cash flows of the Company.
On December 18, 1995, the Louisiana Department of Environmental Quality
advised the Company that the Company, through one of its subsidiaries and
together with several other unaffiliated entities, had been named under
state law as a potentially responsible party with respect to a hazardous
substance site in Shreveport, Louisiana and may be required to share in the
remediation cost, if any, of the site. However, considering the information
currently known about the site and the involvement of the Company and its
subsidiaries with respect to the site, the Company does not believe that
the matter will have a material adverse effect on the financial position,
results of operations or cash flows of the Company.
The Company is a party to litigation (other than that specifically noted)
which arises in the normal course of business. Management regularly
analyzes current information and, as necessary, provides accruals for
probable liabilities on the eventual disposition of these matters.
Management believes that the effect on the Company's results of operations,
financial position or cash flows, if any, from the disposition of these
matters will not be material.
<PAGE>
Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations
General
NorAm Energy Corp., referred to herein together with its consolidated
subsidiaries and divisions (all of which are wholly owned) as "NorAm" or "the
Company", principally conducts operations in the natural gas industry, including
gathering, transmission, marketing, storage and distribution which,
collectively, account for in excess of 90% of the Company's total revenues,
income or loss and identifiable assets. The Company also makes sales of
electricity, non-energy sales and provides certain non-energy services,
principally to certain of its retail gas distribution customers. The reader is
directed to the Company's 1996 Report on Form 10-K for additional information
concerning the Company's various business activities and a discussion of the
Company's significant accounting policies.
Merger With Houston Industries Incorporated
On August 11, 1996, the Company entered into an Agreement and Plan of
Merger (the "Merger Agreement") with Houston Industries Incorporated ("Houston
Industries" or "HI"), Houston Lighting & Power Company ("HL&P") and a
newly-formed Delaware subsidiary of Houston Industries ("HI Merger, Inc.").
Under the Merger Agreement, the Company would merge with and into HI Merger,
Inc. and would become a wholly-owned subsidiary of HII (as defined following).
Houston Industries would merge with and into HL&P, which would be renamed
Houston Industries Incorporated ("HII") (the term "Transaction" refers to the
business combination between Houston Industries and the Company). Consideration
for the purchase of the Company's common stock would be a combination of cash
and shares of HI common stock, valued at approximately $3.8 billion, consisting
of approximately $2.4 billion for the Company's common stock and equivalents and
approximately $1.4 billion in assumption of the Company's debt. Additional
information concerning the Merger Agreement is contained in the Joint Proxy
Statement/Prospectus of Houston Industries, HL&P and the Company dated October
29, 1996 ("the Proxy/Prospectus").
The Merger Agreement was approved and adopted at Special Meetings of
Houston Industries' and the Company's stockholders held on December 17, 1996.
The Company and HI proceeded to obtain required state and municipal regulatory
approvals, all of which have been obtained, and to request an exemption from the
Securities and Exchange Commission ("the SEC") which would allow the Transaction
to take place under its preferred structure without subjecting post-merger HII
to the requirements of the Public Utility Holding Company Act. It is HI's and
the Company's intention to defer the closing of the Transaction until the SEC
issues its ruling on the exemption request although, as set forth in the
Proxy/Prospectus, there are two alternative structures, one of which would not
require SEC approval. Adoption of either of these structures, however, would
require that the Company and HI make new filings to obtain the various state and
municipal regulatory approvals.
In early February 1997, the Federal Energy Regulatory Commission ("the
FERC" or "the Commission") issued an order ("the Initial Order") advising the
Company that the Transaction "...may require Commission approval pursuant to
section 203 of the FPA" (the "FPA" refers to the Federal Power Act), and
directing the Company to file a response within 30 days of the Initial Order
either "...(1) providing arguments as to why the transaction does not require
Commission authorization under section 203 or (2) an application under section
203". In early March 1997, the Company filed a response to the Initial Order
stating its view that the FERC does not have jurisdiction over the Transaction.
Although such response disclaimed any FERC jurisdiction over the Transaction, it
also indicated that one option being considered was to file an application with
the FERC for approval of the Transaction in anticipation of an expedited review
under the FERC's newly-issued merger policy guidelines. On March 27, 1997, the
Company filed an application under section 203 of the FPA (Docket No.
EC97-24-000) seeking FERC approval of the Transaction, although continuing to
assert its position that such approval is not required. On April 30, 1997, the
FERC issued an additional order ("the Jurisdiction Order") in which it found
that "...the proposed merger involves the disposition of NorAm's [NorAm Energy
Services] jurisdictional facilities via a change of control of those facilities
and, thus, falls within the jurisdiction of the Commission under section 203 of
the FPA."
The Company continues to believe that the Transaction will be completed
as contemplated although, in light of the pending regulatory issues as set forth
preceding, the Company cannot predict with any degree of certainty when the
Transaction will be consummated.
<PAGE>
Recent Developments
Regulatory Proceedings
There have been recent developments with respect to regulatory
proceedings, see "Regulatory Matters" following.
International Activities
In early 1997, the Company learned that four consortiums ("the
Consortiums"), each of which included the Company, were the successful bidders
for the right to build and operate natural gas distribution facilities in each
of four defined service areas ("the Concessions") within Colombia. Contracts,
which extend through the year 2014 and grant the exclusive right to distribute
gas to consumers of less than 500 Mcf per day (and the right to compete for
other customers), were awarded in April 1997.
Dividend Declaration
On May 13, 1997, the Company's Board of Directors declared dividends of
$0.07 per share on common stock payable June 13 to owners of record on May 23,
1997.
Regulatory Matters
The FERC accepted NorAm Gas Transmission Company's ("NGT's") 5th annual
FERC Order 528 filing (Docket No. RP97-274) effective April 1, 1997, which
retained the $0.03 per MMBtu commodity surcharge for continued recovery of 75%
of eligible take-or-pay costs, to the extent that collection of such costs is
supported by market conditions. The recovery of these costs, which commenced in
1992, will continue through the year 2002 although, as a result of the
discontinuance of the application of SFAS 71 to NGT as described in the
Company's 1996 Report on Form 10-K, no asset has been recorded in anticipation
of recovery.
On November 1, 1996, both Mississippi River Transmission Corporation
("MRT") and NGT filed to revise their FERC tariffs, incorporating the Gas
Industry Standards Board standards in compliance with FERC Order 587 (Docket No.
RM96-1). These filings set forth each company's standard procedures for business
practices supporting nominations, allocations, balancing, measurement,
invoicing, capacity release, and standardization of electronic communications
between pipelines and their customers. Pursuant to a FERC acceptance order, both
NGT and MRT revised and refiled specified sections of these tariffs in February
1997. Further revisions were made and filed in May 1997 to satisfy a second
compliance order. NGT and MRT also made filings in May 1997 to comply with
additional standards issued in FERC Order 587-C. These standards are effective
November 1997, except for the internet standards which are effective August
1997.
In April 1996, MRT filed a FERC Section 4 rate case (Docket No.
RP96-199) pursuant to the settlement entered into in MRT's last rate case
(Docket No. RP93-4). MRT's proposed tariff rates would increase revenues derived
from jurisdictional service by $14.7 million annually. Motion rates, subject to
refund, were implemented October 1, 1996. As a result of a prehearing conference
in December 1996, another procedural schedule was established, setting a hearing
date of July 29, 1997. On April 30, 1997, MRT filed its rebuttal testimony which
revised the increase in revenue from $14.7 million to $9.9 million.
The Oklahoma Corporation Commission has initiated a rulemaking
proceeding on the unbundling of gas utility services and the restructuring of
the gas industry. The rules will be developed by the parties to the proceeding
throughout the remainder of 1997, with Oklahoma legislative approval and
subsequent implementation scheduled to occur by the summer of 1998. Arkla and
NGT are participating in this proceeding but, as yet, it is unclear what the
final rules will contain or what degree of financial impact, if any, there will
be on the Company.
Material Changes in the Results of Operations
The Company's results of operations are seasonal due to seasonal
fluctuations in the demand for and, to a lesser extent, the price of natural gas
and, accordingly, the results of operations for interim periods are not
necessarily indicative of the results to be expected for an entire year. As
discussed in the Company's 1996 Report on Form 10-K, however, (1) the Company's
regulated businesses have obtained rate design changes which have lessened the
seasonality of the Company's results of operations and further such changes may
occur and (2) the Company is seeking to derive a larger portion of its earnings
from businesses which exhibit less earnings seasonality. In addition to the
demand for and price of natural gas, the Company's results of operations are
significantly affected by regulatory actions (see the discussion of regulatory
matters in the Company's 1996 Report on Form 10-K and "Regulatory Matters"
elsewhere herein), competition and, below the operating income line, by (1) the
level of borrowings and interest rates thereon and (2) income tax expense, see
"Non-Operating Income and Expense" elsewhere herein.
For purposes of discussing its results of operations, the Company
previously segregated its business activities into (1) Natural Gas Distribution,
(2) Interstate Pipelines, (3) Wholesale Energy Marketing, (4) Natural Gas
Gathering, (5) Retail Energy Marketing and (6) Corporate and Other. In
recognition of emerging industry practice as well as (1) the increasing
convergence of the business activities of the Company's two energy marketing
units, (2) the size of the Company's natural gas gathering business relative to
the Company's overall level of business activities and to the Company's other
business units and (3) the significantly different risks, issues and targeted
customers associated with certain activities (principally home care services)
previously included with Retail Energy Marketing, the Company has determined
that its business activities are more appropriately reported and discussed
utilizing the following structure: (1) Natural Gas Distribution, (2) Interstate
Pipelines, (3) Energy Marketing and Gathering and (4) Corporate and Other. The
results of operations for Natural Gas Distribution and Interstate Pipelines have
not changed from previously reported amounts and, due to the relatively
immaterial earnings impact associated with the non-energy-marketing activities
which were previously reported with Retail Energy Marketing but have been
reclassified to Corporate and Other, the operating results for Energy Marketing
and Gathering do not differ materially from the sum of the operating results for
the three previously reported business units which are its principal components.
Following is certain information concerning the Company's operating
income by business unit, followed by detailed discussions of quarter-to-quarter
operating results by individual business unit.
<TABLE>
<CAPTION>
Three Months
Ended March 31 Increase(Decrease)
------------------------------
----------------------------
1997 1996 $ %
------------- ------------- ------------ ------------
<S> <C> <C> <C> <C>
Operating Income(Loss) (millions of dollars)
Natural Gas Distribution (1) $ 112.7 $ 122.4 $ (9.7) (7.9)%
Interstate Pipelines (1) 38.8 30.8 8.0 26.0%
Energy Marketing and Gathering 0.7 21.5 (20.8) (96.7)%
Corporate and Other (2) (7.0) (5.8) (1.2) (20.7)%
------------- ------------- ------------
145.2 168.9 (23.7) (14.0)%
Early Retirement and Severance (3) - (22.3) 22.3 100.0%
------------- ------------- -----------
Consolidated $ 145.2 $ 146.6 $ (1.4) (1.0)%
============= ============= ============
</TABLE>
(1) In 1996, before expenses for early retirement and severance, see (3)
following.
(2) Includes approximately $3.6 million of goodwill amortization in
each quarter presented.
(3) During the first quarter of 1996, the Company recorded significant charges
associated with staffing reductions in "Natural Gas Distribution" and
"Interstate Pipelines", see the individual discussions of the results of
operations for these business units following.
<PAGE>
NATURAL GAS DISTRIBUTION
As more fully described in the Company's 1996 Report on Form 10-K, the
Company's natural gas distribution business is conducted by its Entex,
Minnegasco and Arkla divisions, collectively referred to herein as
"Distribution" or "Natural Gas Distribution". Certain issues exist with respect
to environmental matters, see "Contingencies" elsewhere herein.
During the first quarter of 1996, approximately 100 employees of Entex
accepted an early retirement program and approximately 25 positions were
eliminated at Minnegasco as a result of the reorganization of certain functions,
resulting in a total pre-tax charge of approximately $5.8 million, which amount
is included under the caption "Early retirement and severance" in the
accompanying Statement of Consolidated Income and reported as "Early retirement
and severance" in the following table.
<TABLE>
<CAPTION>
Three Months
Ended March 31 Increase(Decrease)
------------------------------ ------------------------------
DISTRIBUTION 1997 1996 $ %
- ------------
------------- ------------- ------------- -------------
FINANCIAL RESULTS (millions of dollars)
<S> <C> <C> <C> <C>
Natural gas sales $ 868.5 $ 802.5 $ 66.0 8.2%
Transportation revenue 4.5 6.5 (2.0) (30.8)%
Other revenue 8.2 7.2 1.0 13.9%
------------- ------------- -------------
Total operating revenues 881.2 816.2 65.0 8.0%
Purchased gas cost
Unaffiliated 499.8 392.0 107.8 27.5%
Affiliated 116.6 149.3 (32.7) (21.9)%
Operations and maintenance 97.4 99.7 (2.3) (2.3)%
Depreciation and amortization 23.9 23.5 0.4 1.7%
Other operating expenses 30.8 29.3 1.5 5.1%
------------- ------------- -------------
112.7 122.4 (9.7) (7.9)%
Early retirement and severance - 5.8 (5.8) (100.0)%
------------- ------------- -------------
Operating income $ 112.7 $ 116.6 $ (3.9) (3.3)%
============= ============= =============
DISTRIBUTION
OPERATING STATISTICS (billions of cubic feet)
Residential sales 85.4 95.7 (10.3) (10.8)%
Commercial sales 51.8 54.2 (2.4) (4.4)%
Industrial sales 15.3 14.6 0.7 4.8%
Transportation 12.0 13.3 (1.3) (9.8)%
------------- ------------- -------------
Total throughput 164.5 177.8 (13.3) (7.5)%
============= ============= =============
Three Months
Ended March 31
------------------------------------
DEGREE DAYS Normal 1997 1996
----------- --------- ---------
Arkla 1,713 1,453 1,745
Entex 867 874 992
Minnegasco 3,871 3,941 4,276
</TABLE>
Distribution operating income decreased from $122.4 million (before the
charge for early retirement and severance as discussed preceding) in the first
quarter of 1996 to $112.7 million in the first quarter of 1997, a decrease of
$9.7 million (7.9%). This decrease in operating income reflected both increased
operating revenues and increased operating expenses as discussed following.
"Natural gas sales", representing in excess of 98% of Distribution's
total operating revenues in each period presented, increased from $802.5 million
in the first quarter of 1996 to $868.5 million in the first quarter of 1997, an
increase of $66.0 million (8.2%). This net increase was composed of an increase
of approximately $124.5 million attributable to a higher first-quarter 1997
average sales price, partially offset by a decrease of approximately $58.5
million attributable to a decrease in first-quarter 1997 sales volume. This
decrease in sales volume was principally due to warmer first-quarter 1997
weather; 7,013 total degree days in the first quarter of 1996 vs. 6,268 total
degree days in the first quarter of 1997, a decrease of 745 degree days (10.6%).
This decrease in degree days reduced demand for space heating and was largely
responsible for decreases of 10.3 Bcf (10.8%) and 2.4 Bcf (4.4%) in residential
and commercial sales volumes, respectively. The increase in the average sales
price in the first quarter of 1997 was principally due to an increase in the
average cost of gas (a component of the sales price) as discussed following and,
to a lesser extent, rate increases obtained in certain jurisdictions, see
"Regulatory Matters" included under "Management Analysis" in the Company's 1996
Report on Form 10-K.
"Purchased gas cost" increased from $541.3 million in the first quarter
of 1996 to $616.4 million in the first quarter of 1997, an increase of $75.1
million (13.9%). This net increase was composed of an increase of approximately
$114.6 million attributable to a higher first-quarter 1997 average cost of
purchased gas, partially offset by a decrease of approximately $39.5 million
attributable to the decreased first-quarter 1997 sales volume as discussed
preceding. The increase in the weighted average cost of gas from approximately
$3.29 per Mcf in the first quarter of 1996 to approximately $4.04 per Mcf in the
first quarter of 1997, an increase of approximately $0.75 per Mcf (22.8%),
principally was reflective of an overall increase in the market price of gas.
The gross sales margin ("Natural gas sales" minus total purchased gas
cost) decreased from $261.2 million in the first quarter of 1996 to $252.1
million in the first quarter of 1997, a decrease of $9.1 million (3.5%). This
net decrease reflected (1) the largely weather-related 12.7 Bcf decrease in
total residential and commercial sales volume in the first quarter of 1997
which, together with a minor increase in industrial sales volume, resulted in a
net margin decrease of approximately $19.1 million, partially offset by (2) a
first-quarter 1997 margin increase of approximately $10.0 million attributable
to an increase in the average margin per unit of sales, principally due to the
rate increases obtained in certain jurisdictions, each as discussed preceding.
Operating expenses, exclusive of purchased gas cost and the
first-quarter 1996 charge for early retirement and severance, decreased from
$152.5 million in the first quarter of 1996 to $152.1 million in the first
quarter of 1997, as a decrease of approximately $2.3 million (2.3%) in
"Operations and maintenance" was largely offset by increases of approximately
$1.5 million (5.1%) and $0.4 million (1.7%) in "Other operating expenses" and
"Depreciation and amortization", respectively. The increases in "Depreciation
and amortization" and "Other operating expenses" were principally due to
increased investment, while the decrease in "Operations and maintenance" was
largely due to cost savings associated with increased operating efficiency.
<PAGE>
INTERSTATE PIPELINES
As more fully described in the Company's 1996 Report on Form 10-K, the
Company's interstate pipeline business is conducted by NorAm Gas Transmission
Company ("NGT") and Mississippi River Transmission Corporation ("MRT"), together
with certain subsidiaries and affiliates, collectively referred to herein as
"Pipeline" or "Interstate Pipelines". The Company has a commitment to refund
certain amounts pursuant to a transportation agreement, is a party to certain
claims involving its gas purchase contracts and has certain concerns with
respect to environmental matters, see "Commitments" and "Contingencies"
elsewhere herein.
During the first quarter of 1996, the Company instituted a
reorganization plan ("the Reorganization") affecting NGT and MRT. The
Reorganization, which included the reorganization of a number of departments and
the redesign of a number of processes, was designed to allow Pipeline to operate
more efficiently, thus improving its ability to compete in its market areas.
Approximately 275 positions were eliminated pursuant to the Reorganization,
resulting in a pre-tax charge of approximately $16.5 million, included under the
caption "Early retirement and severance" in the accompanying Statement of
Consolidated Income and reported as "Early retirement and severance" in the
following table.
<TABLE>
<CAPTION>
Three Months
Ended March 31 Increase(Decrease)
-------------------------------- ------------------------------
INTERSTATE PIPELINES 1997 1996 $ %
- --------------------
--------------- ------------- ------------- -------------
FINANCIAL RESULTS (millions of dollars)
<S> <C> <C> <C> <C>
Natural gas sales
Sales to Distribution - $ 27.0 $ (27.0) (100.0)%
Industrial and other $ 13.6 5.7 7.9 138.6%
--------------- ------------- -------------
Total gas sales revenue 13.6 32.7 (19.1) (58.4)%
Transportation revenue
Distribution 34.4 25.2 9.2 36.5%
Unaffiliated 36.2 39.9 (3.7) (9.3)%
--------------- ------------- -------------
Total transportation revenue 70.6 65.1 5.5 8.4%
--------------- ------------- -------------
Total operating revenues 84.2 97.8 (13.6) (13.9)%
Purchased gas cost 11.0 27.4 (16.4) (59.9)%
Operations and maintenance expense 11.8 14.9 (3.1) (20.8)%
Depreciation and amortization 7.3 7.6 (0.3) (3.9)%
General, administrative and other 15.3 17.1 (1.8) (10.5)%
--------------- ------------- -------------
38.8 30.8 8.0 26.0%
Early retirement and severance - 16.5 (16.5) (100.0)%
--------------- ------------- -------------
Operating income $ 38.8 $ 14.3 $ 24.5 171.3%
=============== ============= =============
INTERSTATE PIPELINES
OPERATING STATISTICS (million MMBtu)
Natural gas sales
Sales to Distribution - 9.7 (9.7) (100.0)%
Sales for resale and other 4.7 2.8 1.9 67.9%
--------------- ------------- -------------
Total sales 4.7 12.5 (7.8) (62.4)%
--------------- ------------- -------------
Transportation
Distribution 42.2 48.7 (6.5) (13.3)%
Other 207.7 255.1 (47.4) (18.6)%
--------------- ------------- -------------
Total transportation 249.9 303.8 (53.9) (17.7)%
Elimination (1) (4.4) (11.8) 7.4 62.7%
--------------- ------------- -------------
Total throughput 250.2 304.5 (54.3) (17.8)%
=============== ============= =============
</TABLE>
(1) This elimination is made to prevent the overstatement of total
throughput which would otherwise occur due to physical volumes which
were both sold and transported by Pipeline and are therefore included
in the above volumetric data in both categories. No elimination is made
for volumes of 49.5 million MMBtu and 60.7 million MMBtu in the three
months ended March 31, 1997 and 1996, respectively, which were
transported on both the NGT and MRT systems.
Interstate Pipeline operating income for the first quarter of 1997 was
$38.8 million, an increase of $24.5 million (171.3%) from the $14.3 million
reported for the first quarter of 1996. This increase was principally
attributable to the $16.5 million first-quarter 1996 charge for early retirement
and severance as described preceding. Exclusive of this charge, Pipeline
operating income for the first quarter of 1997 increased by approximately $8.0
million (26.0%) from the first quarter of 1996. This increase was primarily
attributable to (1) cost savings associated with the Reorganization (see the
discussion preceding), (2) the first-quarter 1997 completion of settlement
negotiations with a distribution affiliate on terms more favorable than
anticipated, resulting in an earnings increase of approximately $7.3 million and
(3) the expiration, in September 1996, of certain contractual provisions which
had placed a rate "cap" on transportation rates for deliveries at certain points
on Pipeline's system. These positive impacts were partially offset by the
elimination of margins associated with gas sales to Distribution. As discussed
in the Company's 1996 Report on Form 10-K, the contract pursuant to which such
sales were made expired in September 1996. Following are discussions of
individual financial statement line item variances.
"Total gas sales revenue" decreased from $32.7 million in the first
quarter of 1996 to $13.6 million in the first quarter of 1997, a decline of
$19.1 million (58.4%). This decrease, the net of (1) a $20.4 million decrease
associated with reduced first-quarter 1997 sales volume and (2) an increase of
$1.3 million due to an increased first-quarter 1997 average sales price, was
principally attributable to the expiration of the sale contract with
Distribution as discussed preceding. This unfavorable revenue impact was
partially offset by an increase of $7.9 million (138.6%) in "Industrial and
other" revenues, primarily due to (1) a first-quarter 1997 increase of
approximately $0.86 per MMBtu (42.1%) in the average sales price (due, in part,
to an increase in the cost of gas, a component of the sales rate, as discussed
following) and (2) increased sales volumes (principally to a marketing
affiliate), which factors were responsible for $4.0 million (50.6%) and $3.9
million (49.4%), respectively, of the total increase.
Revenue from transportation for Distribution increased by approximately
$9.2 million (36.5%) from the first quarter of 1996 to the first quarter of 1997
principally due to the favorable conclusion of settlement negotiations with a
distribution affiliate and the expiration of rate "cap" provisions, each as
discussed preceding. These favorable impacts were partially offset by a
reduction in the Gas Research Institute ("GRI") surcharge as discussed
following. "Unaffiliated" transportation revenues decreased from $39.9 million
in the first quarter of 1996 to $36.2 million in the first quarter of 1997, a
decrease of approximately $3.7 million (9.3%). This decrease was attributable to
a number of factors, including (1) a lower surcharge for gas supply realignment
("GSR") cost as discussed following, (2) first-quarter 1996 penalties collected
from customers for demand in excess of contracted quantities or tariff
provisions and (3) changes in the relative pricing of Mid-Continent gas supplies
("pricing differentials"). Changes in these pricing differentials have an impact
(positive or negative) on certain of Pipeline's transportation rates under
contracts with market-sensitive pricing provisions. During the first quarter of
1996, the average price differential between Mid-Continent and Gulf Coast gas
supplies was $0.91 per MMBtu compared to an average differential of only $0.03
per MMBtu in the first quarter of 1997. Total transportation revenues were also
unfavorably affected by a reduction of approximately 53.9 million MMBtu (17.7%)
in transported volumes from the first quarter of 1996 to the first quarter of
1997 although, due to Pipeline's "straight-fixed-variable" rate design which
results in recovery of fixed costs through a demand charge, only a relatively
small portion of the overall transportation rate varies directly with the volume
actually transported.
"Purchased gas cost" decreased from approximately $27.4 million in the
first quarter of 1996 to approximately $11.0 million in the first quarter of
1997, a decrease of approximately $16.4 million (59.9%). This decrease was
principally due to a $17.1 million decrease associated with the decreased
first-quarter 1997 sales volume as described preceding, partially offset by an
increase of approximately $0.7 million associated with an increase of
approximately 6.8% in the average cost of purchased gas from approximately $2.19
per MMBtu in the first quarter of 1996 to approximately $2.34 per MMBtu in the
first quarter of 1997.
"Operations and maintenance expense" decreased from $14.9 million in
the first quarter of 1996 to $11.8 million in the first quarter of 1997, a
decrease of $3.1 million (20.8%), principally due to a reduction in operating
expenses (primarily labor and labor-related costs) associated with the
Reorganization as discussed preceding. Although the Reorganization was
implemented in February 1996, certain positions were not eliminated until after
the first quarter of 1996, creating a favorable variance in the
quarter-to-quarter comparison. Additional favorable variance is due to reduced
transportation expense reflecting reduced GSR revenues. Pursuant to the terms of
a FERC settlement, Pipeline is allowed to recover certain GSR costs, and such
costs are expensed as the associated revenue is billed. "Depreciation and
amortization" decreased by approximately $0.3 million (3.9%) from the first
quarter of 1996 to the first quarter of 1997, principally due to the completion,
in December 1996, of the amortization period of certain previously capitalized
costs (principally computer software).
"General, administrative and other" decreased by approximately $1.8
million (10.5%) from the first quarter of 1996 to the first quarter of 1997 due
to several factors including (1) cost reductions associated with the
Reorganization, (2) reductions in allocated costs from the parent company and
(3) a retroactive adjustment for payments made to the GRI (such amounts are
offset in revenues).
<PAGE>
ENERGY MARKETING AND GATHERING
The Company's energy marketing and natural gas gathering activities are
carried out by NorAm Energy Services, Inc., NorAm Energy Management, Inc. and
NorAm Field Services Corp., together with certain subsidiaries and affiliates,
collectively ("Energy Marketing and Gathering" or "EM&G"). This business unit is
principally composed of the Company's previously reported "Wholesale Energy
Marketing", "Retail Energy Marketing" and "Natural Gas Gathering" business units
(see "General" elsewhere herein). A description of the business activities
conducted by each of these formerly separately-reported business units is
contained in the separate business unit discussions included with "Material
Changes in the Results of Continuing Operations" under "Management Analysis" in
the Company's 1996 Report on Form 10-K. The nature of natural gas marketing
activities is such that contractual disputes arise, see "Contingencies"
elsewhere herein.
<TABLE>
<CAPTION>
Three Months
Ended March 31 Increase(Decrease)
------------------------------ ------------------------------
ENERGY MARKETING AND GATHERING 1997 1996 $ %
- ------------------------------
------------- ------------- ------------- -------------
FINANCIAL AND OPERATING RESULTS (millions of dollars)
<S> <C> <C> <C> <C>
Operating Revenues
Natural gas sales
Unaffiliated sales $ 867.0 $ 515.7 $ 351.3 68.1%
Sales to Distribution 53.8 43.8 10.0 22.8%
Sales to Pipeline - 20.3 (20.3) (100.0)%
Other affiliated sales 0.3 - 0.3 N/A
------------- ------------- -------------
Total gas sales revenue 921.1 579.8 341.3 58.9%
------------- ------------- -------------
Electricity sales 110.9 4.4 106.5 N/M (1)
Transportation 1.0 1.2 (0.2) (16.7)%
Gathering 7.7 6.3 1.4 22.2%
Products extraction 1.8 2.2 (0.4) (18.2)%
Other 0.7 0.6 0.1 16.7%
------------- ------------- -------------
Total operating revenues 1,043.2 594.5 448.7 75.5%
------------- ------------- -------------
Operating Expenses
Purchased gas costs
Unaffiliated 897.5 534.3 363.2 68.0%
Affiliated 11.3 4.6 6.7 145.7%
------------- ------------- -------------
Total purchased gas cost 908.8 538.9 369.9 68.6%
Transportation and storage expense 8.8 18.5 (9.7) (52.4)%
Electricity purchases and transmission costs 111.5 4.1 107.4 N/M
Cost of sales 0.7 1.2 (0.5) (41.7)%
Operation and maintenance 3.4 3.7 (0.3) (8.1)%
Depreciation 0.8 0.7 0.1 14.3%
General and administrative 7.6 5.2 2.4 46.2%
Taxes other than income 0.9 0.7 0.2 28.6%
------------- ------------- -------------
Operating income $ 0.7 $ 21.5 $ (20.8) (96.7)%
============= ============= =============
Natural gas sales volume (Bcf) 313.5 243.8 69.7 28.6%
Transportation volumes (Bcf) 7.4 8.5 (1.1) (12.9)%
Gathering volumes (Bcf) 59.6 55.8 3.8 6.8%
</TABLE>
(1) Indicates that the item is not meaningful.
Operating income for EM&G in the first quarter of 1997 was $0.7
million, a decrease of $20.8 million (96.7%) from the $21.5 million earned in
the first quarter of 1996. This decrease principally was reflective of (1)
hedging losses associated with anticipated first-quarter 1997 sales under
peaking contracts and (2) losses from the sale of natural gas held in storage
and unhedged, in each case as described in the Company's 1996 Report on Form
10-K. In addition, (1) volatile and, in some cases, declining natural gas prices
during the first quarter of 1997 had an unfavorable impact on gas sale margins
and (2) as described in the Company's 1996 Report on Form 10-K, first-quarter
1996 results reflected the favorable impact of relatively colder weather. This
colder weather during the first quarter of 1996 resulted in shortages of
pipeline capacity at various locations, allowing EM&G to collect significant
premiums from certain customers who wished to avoid interruption of supply.
Significant variances in individual income statement line items are discussed
following.
<PAGE>
"Total gas sales revenue" increased from $579.8 million in the first
quarter of 1996 to $921.1 million in the first quarter of 1997, an increase of
$341.3 million (58.9%). Approximately $175.5 million (51.4%) of this increase
was attributable to an increase in the first-quarter 1997 average sales price,
and the balance of approximately $165.8 million (48.6%) was attributable to an
increase in first-quarter 1997 natural gas sales volume. The increase of
approximately $0.56 per Mcf (23.5%) in the average sales price of natural gas
from approximately $2.38 per Mcf in the first quarter of 1996 to approximately
$2.94 per Mcf in the first quarter of 1997 principally was reflective of an
increase in the average cost of purchased gas during the first quarter of 1997
as discussed following (the cost of gas is a component of the overall sales
rate), partially offset by a decrease in the first-quarter 1997 average margin
per unit of sales. The increase of approximately 69.7 Bcf (28.6%) in
first-quarter 1997 natural gas sales volume was principally due to the expansion
of EM&G's marketing efforts. Utilizing an increased staff of marketers and
additional office locations as discussed in the Company's 1996 Report on Form
10-K, EM&G continued to increase its efforts toward becoming a nationwide
marketing company with an emphasis on increasing market share, principally
targeting end-use customers in the industrial, local gas distribution and
electric generation sectors.
Revenues from natural gas gathering and products extraction activities
increased from approximately $8.5 million in the first quarter of 1996 to
approximately $9.5 million in the first quarter of 1997, an increase of
approximately $1.0 million (11.8%). Approximately $0.5 million (50.0%) of this
increase was attributable to an increase in first-quarter 1997 volume and the
remaining 50% was attributable to an increase in the first-quarter 1997 average
unit revenue. The increase of approximately 3.8 Bcf (6.8%) in first-quarter 1997
gathering volume reflects new well connects and the addition of gathering assets
previously owned by Pipeline, partially offset by the negative impact of
producer shut-ins, well freeze-offs, curtailments and capacity constraints. The
increase of approximately $0.13 per Mcf in the first-quarter 1997 average unit
revenue was principally due to (1) new compression, nomination and balancing
services provided to customers and (2) higher first-quarter 1997 liquids prices.
"Total purchased gas costs" were $908.8 million in the first quarter of
1997, an increase of $369.9 million (68.6%) from the first quarter of 1996.
Approximately $215.8 million (58.3%) of this increase was attributable to an
increase of approximately $0.69 per Mcf (31.1%) in the first-quarter 1997
average cost of purchased gas, and the balance of approximately $154.1 million
(41.7%) was attributable to the increased first-quarter 1997 sales volumes as
discussed preceding. The increase in the first-quarter 1997 average cost of
purchased gas principally was reflective of (1) an increase in the spot market
price of natural gas and (2) the impact of certain of the Company's risk
management and storage gas activities as discussed preceding.
"Transportation and storage expense" decreased from $18.5 million in
the first quarter of 1996 to $8.8 million in the first quarter of 1997, a
decrease of $9.7 million (52.4%). This net decrease was composed of a decrease
of approximately $15.0 million attributable to a $0.048 per Mcf (63.0%) decline
in the first-quarter 1997 unit cost of transportation and storage, partially
offset by an increase of approximately $5.3 million due to the increased
first-quarter 1997 sales volume as discussed preceding. The decrease in the
first-quarter 1997 unit cost of transportation and storage was principally due
to increased 1997 usage of interruptible and capacity release transportation in
lieu of firm transportation arrangements.
"Electricity sales" and "Electricity purchases and transmission costs"
of $110.9 million and $111.5 million, respectively, in the first quarter of 1997
represented significant increases over the corresponding amounts for 1996,
although the gross margin from power marketing declined from approximately $0.3
million in the first quarter of 1996 to a loss of approximately $0.6 million in
the first quarter of 1997, as the significant increase in volume was more than
offset by a decrease in unit margins. During the latter part of 1996 and early
1997, NES continued to increase both its emphasis on electricity sales and its
electricity marketing staff in anticipation of increased access to electric
power markets. The decrease in first-quarter 1997 unit margins from power
marketing was principally attributable to the volatility and limited liquidity
in wholesale electric power markets which increase the intra-month price risk
associated with such activities.
The first-quarter 1997 margin on gas sales was $3.5 million, a decrease
of $18.9 million (84.4%) from the $22.4 million earned in the first quarter of
1996. This net decrease in gas sales margin was attributable to a decrease of
approximately $25.3 million due to a decrease of approximately $0.081 per Mcf in
the first-quarter 1997 average margin per unit of sales, partially offset by an
increase of approximately $6.4 million associated with the increased
first-quarter 1997 sales volume as discussed preceding. The decreased
first-quarter 1997 average margin per unit of sales was principally due to the
losses associated with the sale of gas-in-storage, sales under peaking contracts
and relatively warmer first-quarter 1997 weather, each as discussed preceding.
The margin from natural gas gathering and products extraction
activities increased from approximately $8.0 million in the first quarter of
1996 to approximately $9.9 million in the first quarter of 1997, an increase of
approximately $1.9 million (23.8%). Approximately $1.4 million (73.7%) of this
increase was attributable to an increase in the first-quarter 1997 average
margin per unit of throughput and the balance of approximately $0.5 million
(26.3%) was attributable to increased first-quarter 1997 gathering volumes as
discussed preceding. The increased first-quarter 1997 average margin per unit of
throughput was principally due to new services provided to customers and
increased first-quarter 1997 liquids prices, each as discussed preceding.
Other operating expenses (exclusive of "Purchased gas cost",
"Transportation and storage expense", "Electricity purchases and transmission
costs" and "Cost of sales") increased from approximately $10.3 million in the
first quarter of 1996 to approximately $12.7 million in the first quarter of
1997, an increase of approximately $2.4 million (23.3%). This increase was
principally due to increased general and administrative costs (principally
payroll and benefits) associated with staffing increases made in support of the
increased sales and expanded marketing efforts as described preceding.
As further discussed in the Company's 1996 Report on Form 10-K, the
Company's earnings from its gas supply, marketing, gathering and transportation
activities are subject to variability based on fluctuations in both the price of
natural gas and the value of transportation as measured by changes in the
delivered price of natural gas at various points in the nation's natural gas
grid. In order to mitigate this financial risk both for itself and for certain
customers who have requested the Company's assistance in managing similar
exposures, the Company routinely enters into natural gas swaps, futures
contracts and options. None of these derivatives are held for speculative
purposes and, in general, the Company's risk management policy requires that
these positions be offset by positions in physical transactions (actual or
anticipated) or in other derivatives.
In the table which follows, the term "notional amount" refers to the
contract unit price times the contract volume for the relevant derivative
category and, in general, such amounts are not indicative of the cash
requirements associated with these derivatives. The notional amount is intended
to be indicative of the Company's level of activity in such derivatives,
although the amounts at risk are significantly smaller because, in view of the
price movement correlation required for hedge accounting, changes in the market
value of these derivatives generally are offset by changes in the value
associated with the underlying physical transactions or in other derivatives.
When derivative positions are closed out in advance of the underlying commitment
or anticipated transaction, however, the market value changes may not offset due
to the fact that price movement correlation ceases to exist when the positions
are closed. Under such circumstances, gains or losses are deferred and
recognized when the underlying commitment or anticipated transaction was
scheduled to occur. Following is certain information concerning the Company's
derivative activities:
<TABLE>
<CAPTION>
Natural Gas Swaps (1)
(volumes in Bcf's, dollars in millions)
Volume
---------------------------------- Estimated
Fixed Price Fixed Price Mkt. Value
Payor Receiver Gain (2)
--------------- --------------- ----------------
<S> <C> <C> <C>
March 31, 1997 144.9 52.4 12.3
December 31, 1996 126.6 52.9 9.7
March 31, 1996 230.8 204.0 4.1
</TABLE>
<TABLE>
<CAPTION>
Natural Gas Futures (3)
(volumes in Bcf's, dollars in millions)
Purchased Sold
---------------------------------- --------------------------------- Estimated
Notional Notional Mkt. Value
Volume Amount Volume Amount Gain (2)
--------------- ---------------- -------------- --------------- ----------------
<S> <C> <C> <C> <C> <C>
March 31, 1997 20.1 42.1 15.3 31.7 0.4
December 31, 1996 23.7 64.1 13.6 40.0 0.1
March 31, 1996 14.5 27.7 9.3 19.5 2.7
</TABLE>
(1) The financial impact of these swaps was to decrease earnings by $(1.0)
million, $(1.0) million and $(6.1) million during 1996 and the quarters
ended March 31, 1997 and 1996, respectively.
(2) Represents the amount which would have been realized upon termination of
the relevant derivative as of the date indicated. As more fully discussed
in the Company's 1996 Report on Form 10-K, in the case of swaps associated
with certain agreements pursuant to which the Company has committed to
supply gas to a distribution affiliate through April 1999, no earnings
impact is expected due to the existing accruals. Swaps associated with
these commitments and included above had a fair market value of $1.2
million at March 31, 1997.
(3) The financial impact of these futures was to increase(decrease) earnings by
$(9.3) million, $(22.6) million and $(5.5) million during 1996 and the
quarters ended March 31, 1997 and 1996, respectively.
At March 31, 1997, the Company held options covering the purchase of
6.7 Bcf of gas, principally in conjunction with the commitment to supply gas to
a distribution affiliate as discussed preceding. The majority of these options,
due to their nature and term, have no readily available market value and the
market value of the remainder is not material.
<PAGE>
CORPORATE AND OTHER
The operating loss for "Corporate and Other" increased from $(5.8)
million in the first quarter of 1996 to $(7.0) million in the first quarter of
1997, an increase of approximately $1.2 million (20.7%). This increased loss was
principally due to 1997 development costs associated with the Company's utility
services (principally line locating) and consumer services (principally home
security) businesses, partially offset by improved results from the Company's
existing appliance sales and service activities.
NON-OPERATING INCOME AND EXPENSE
Net income for the three months ended March 31, 1997 was $68.6 million,
an increase of approximately $7.7 million (12.6%) from the corresponding quarter
of 1996 while, as discussed preceding, operating income decreased by
approximately $1.4 million (1.0%) during the same period. The components of this
net decrease of $9.1 million in net expense below the operating income line were
as follows:
<TABLE>
<CAPTION>
Three Months
Ended March 31 Increase(Decrease)
-------------------------------- ----------------------------
1997 1996 $ %
--------------- ------------- ------------- -----------
(millions of dollars)
<S> <C> <C> <C> <C> <C>
Interest expense, net (1) $ 35.5 $ 36.2 $ (0.7) (1.9)% (2)
Dividend on Trust Preferred 2.7 - 2.7 N/A
Other, net (1) (6.3) 3.4 (9.7) (285.3)% (3)
Provision for income taxes 44.9 45.8 (0.9) (2.0)% (4)
Extraordinary items (0.2) 0.3 (0.5) (166.7)%
--------------- ------------- -------------
$ 76.6 $ 85.7 $ (9.1) (10.6)%
=============== ============= =============
</TABLE>
(1) The costs associated with the Company's Receivables Facility
(approximately $3.0 million in each period presented) are included with
"Other, net" in 1996 and with "Interest expense, net" in 1997, see (2)
following and "Net Cash Flows from Financing Activities" under "Liquidity
and Capital Resources" elsewhere herein.
(2) After adjustment to remove costs associated with the Receivables Facility
from first-quarter 1997 interest expense, interest expense decreased by
approximately $3.7 million from the first quarter of 1996 to the first
quarter of 1997. Substantially all of this decrease was attributable to a
reduced level of debt during 1997.
(3) After adjustment to remove the first-quarter 1996 costs associated with
the Receivables Facility, "Other, net" improved from expense of
approximately $0.4 million in the first quarter of 1996 to income of
approximately $6.3 million in the first quarter of 1997. Substantially all
of this favorable variance was attributable to the close-out of certain
interest rate swaps, see "Net Cash Flows from Financing Activities"
elsewhere herein.
(4) This favorable variance reflects a $3.6 million reduction in income tax
expense attributable to a decrease in the first-quarter 1997 interim
effective tax rate (principally state income taxes), partially offset by a
$2.7 million increase in income tax expense due to increased first-quarter
1997 pre-tax income.
<PAGE>
Liquidity and Capital Resources
The table below illustrates the sources of the Company's invested capital
during the last four years and at March 31, 1997 and 1996.
<TABLE>
<CAPTION>
March 31, December 31,
------------------------- ----------------------------------------------------
INVESTED CAPITAL 1997 1996 1996 1995 1994 1993
- -------------------------------------- ------------ ------------ ------------ ------------ ------------ ------------
(millions of dollars)
<S> <C> <C> <C> <C> <C> <C>
Long-Term Debt $1,047.5 $1,467.5 $1,054.2 $1,474.9 $1,414.4 $1,629.4
Trust Preferred (1) 164.4 - 167.8 - - -
Common Equity (2) 864.7 701.6 800.5 637.3 587.4 578.0
Preferred Stock (3) - 130.0 - 130.0 130.0 130.0
------------ ------------ ------------ ------------ ------------ ------------
Total Capitalization 2,076.6 2,299.1 2,022.5 2,242.2 2,131.8 2,337.4
Short-Term Debt 590.0 48.8 392.0 128.8 274.6 192.4
------------ ------------ ------------ ------------ ------------ ------------
Total Invested Capital $2,666.6 $2,347.9 $2,414.5 $2,371.0 $2,406.4 $2,529.8
============ ============ ============ ============ ============ ============
Receivables Facility (4) $ 225.0 $ 193.3 $ 235.0 $ 235.0 $ 192.8 $ 226.4
============ ============ ============ ============ ============ ============
Total Capitalization:
Long-Term Debt 50.4% 63.8% 52.1% 65.8% 66.3% 69.7%
Trust Preferred (1) 7.9% - 8.3% - - -
Common Equity 41.7% 30.5% 39.6% 28.4% 27.6% 24.7%
Preferred Stock - 5.7% - 5.8% 6.1% 5.6%
Total Invested Capital:
Senior Debt (4)(5) 60.4% 67.3% 58.8% 70.6% 72.4% 74.3%
Total Debt (4) 64.4% 67.3% 63.5% 70.6% 72.4% 74.3%
</TABLE>
(1) Company-Obligated Mandatorily Redeemable Convertible Preferred Securities
of Subsidiary Trust Holding Solely $177.8 Million Principal Amount of 6.25%
Convertible Subordinated Debentures due 2026 of NorAm Energy Corp.
(2) Includes unrealized gains on its investment in Itron, Inc. ("Itron"), net
of tax of $1.2 million, $25.8 million, $15.3 million and $2.6 million at
March 31, 1997 and 1996 and December 31, 1995 and 1994, respectively. The
unrealized gain at December 31, 1996 was not material. At May 6, 1997, the
Company's investment in Itron had increased to a market value of
approximately $35.1 million, representing an unrealized gain of
approximately $5.4 million, net of tax of approximately $3.1 million.
(3) Exchanged for the Company's 6% Convertible Subordinated Debentures due 2012
in June 1996.
(4) Proceeds received pursuant to the Company's Receivables Facility have been
included with "Senior Debt" and "Total Debt" for all periods for purposes
of calculating the ratios of "Senior Debt" and "Total Debt" to "Total
Invested Capital", although such proceeds are not included with "Short-Term
Debt" on the Company's Consolidated Balance Sheet (or in the table
preceding) prior to January 1, 1997, see "Receivables Facility" under "Net
Cash Flows from Financing Activities" elsewhere herein.
(5) Excludes the Company's 6% Convertible Subordinated Debentures due 2012
("the Subordinated Debentures"), outstanding beginning in June 1996. At
December 31, 1996 and March 31, 1997, $122.7 million and $117.0 million,
respectively, of the Subordinated Debentures were outstanding.
CASH FLOW ANALYSIS
The Company's cash flows, like its results of operations, are seasonal
and, therefore, the cash flows experienced during an interim period are not
necessarily indicative of the results to be expected for an entire year. The
following discussion of cash flows should be read in conjunction with the
accompanying Statement of Consolidated Cash Flows and related supplemental cash
flow information, and with the cash flow information included in the Company's
1996 Report on Form 10-K.
<PAGE>
Net Cash Flows from Operating Activities
As indicated in the accompanying Statement of Consolidated Cash Flows, "Net
cash provided by operating activities" decreased from approximately $125.8
million in the first quarter of 1996 to $97.6 million in the first quarter of
1997. This decrease of approximately $28.2 million (22.4%) was principally
attributable to:
* A decrease of approximately $38.8 million (45.9%) in first-quarter 1997
cash provided from miscellaneous working capital items, principally
"Other current assets" and "Other current liabilities". The increase of
approximately $34.8 million in first-quarter 1997 cash used for the net
of "Other current assets" and "Other current liabilities" was
principally due to the relatively larger net liability balance existing
at December 31, 1996 (in comparison to December 31, 1995) which was
paid/collected during the first quarter of 1997.
* A decrease of approximately $23.2 million (77.8%) in first-quarter 1997
cash provided by deferred gas costs, principally due to (1) the
relatively larger December 31, 1995 balance (in comparison to December
31, 1996) which was collected during the first quarter of 1996, and (2)
the relatively larger balance of refundable amounts built up during the
first quarter of 1996.
* A decrease of approximately $4.6 million (3.9%) in cash provided from
income before non-cash charges and credits during the first quarter of
1997, see "Material Changes in the Results of Continuing Operations"
elsewhere herein.
* A decrease of approximately $3.9 million (54.2%) in first-quarter 1997
recoveries under gas contract settlements as the underlying agreements
continue to unwind.
These unfavorable impacts were partially offset by:
* A decrease of approximately $42.3 million (37.5%) in first-quarter 1997
cash used for the net of accounts receivable and accounts payable,
principally due to the relatively larger net asset balance existing at
December 31, 1996 (in comparison to December 31, 1995) which was
collected/paid during the first quarter of 1997. In addition, cash used
for the net of accounts receivable and accounts payable for the first
quarter of 1996 included a net cash outflow of approximately $41.7
million associated with utilization of the Company's Receivables
Facility. Cash flows associated with utilization of this facility are
included with "Net Cash Flows from Financing Activities" beginning with
January 1, 1997, see the discussion following.
As further described in the Company's 1996 Report on Form 10-K, the
Company has a Receivables Facility pursuant to which it transfers an interest in
a pool of accounts receivables to a third party in exchange for cash. Prior to
January 1, 1997, transfers of receivables under this facility were accounted for
as sales, with net cash inflows or outflows included with "Cash Flows from
Operating Activities" in the Company's Statement of Consolidated Cash Flows.
Subsequent to January 1, 1997 and in accordance with the provisions of Statement
of Financial Accounting Standards No. 125, "Accounting for Transfers and
Servicing of Financial Assets and Extinguishment of Liabilities" which does not
allow retroactive application, such cash flows are included with financing
activities, see "Net Cash Flows from Financing Activities" elsewhere herein.
Net Cash Flows from Investing Activities
The Company's capital expenditures by business unit for the three months
ended March 31, 1997 and 1996 were as follows:
<TABLE>
<CAPTION>
Three Months
Ended March 31 Increase(Decrease)
--------------------------- ----------------------------
1997 1996 $ %
------------ ------------ ------------ -------------
(millions of dollars)
<S> <C> <C> <C> <C>
Natural Gas Distribution $ 18.9 $ 21.9 $ (3.0) (13.7)%
Interstate Pipelines 1.9 2.3 (0.4) (17.4)%
Energy Marketing and Gathering 4.6 0.8 3.8 475.0%
Corporate and Other 1.3 0.2 1.1 550.0%
------------ ------------ ------------
Consolidated $ 26.7 $ 25.2 $ 1.5 6.0%
============ ============ ============
</TABLE>
As indicated in the preceding table, the Company's capital expenditures
increased from $25.2 million in the first quarter of 1996 to $26.7 million in
the first quarter of 1997, an increase of approximately $1.5 million (6.0%), as
increases in Energy Marketing and Gathering and Corporate and Other were
partially offset by a decrease in Natural Gas Distribution. The increase of
approximately $3.8 million in EM&G was principally due to increased
first-quarter 1997 expenditures in the Company's natural gas gathering business
for (1) increased compression and (2) new facilities and expansion. The increase
of approximately $1.1 million in Corporate and Other was principally due to the
acquisition, in March 1997, of certain home security contracts in Little Rock,
Arkansas by NorAm Consumer Services. The decrease of approximately $3.0 million
(13.7%) in Distribution was principally due to decreased first-quarter 1997
expenditures at the Company's Minnegasco and Arkla divisions, principally for
water treatment, computers, meter reading equipment, general equipment and
replacements of transportation equipment.
Net Cash Flows from Financing Activities
The reader is directed to the Company's 1996 Report on Form 10-K for
additional information concerning the Company's outstanding debt and equity
securities, financing facilities and recent financing transactions.
Short-Term Financing
As further discussed in the Company's 1996 Report on Form 10-K, the
Company's principal sources of short-term liquidity are (1) its December 1995
unsecured Credit Agreement ("the Credit Facility") with Citibank, N.A., as Agent
and a group of eighteen other commercial banks which provides a $400.0 million
commitment to the Company through December 11, 1998, (2) the Company's
Receivables Facility as described following and (3) informal bank lines of
credit. Following is selected information concerning the Company's short-term
bank borrowings.
<TABLE>
<CAPTION>
Short-Term As of (1)
- ---------- ----------------------------------------- Three Months Ended March 31 or
Bank Borrowings Amount Borrowed Twelve Months Ended December 31
- --------------- -------------------------- Weighted ---------------------------------------------------
(dollars in millions) The Average Weighted Weighted Maximum
Credit Informal Interest Average Average Amount
Facility Lines Rate (2) Borrowed (2) Rate (2) Borrowed (2)
------------- ------------ -------------- ------------------ ------------- -----------------
<S> <C> <C> <C> <C> <C> <C>
March 31, 1997 $ 70.0 $ 17.0 6.17% $ 105.5 5.80% $ 175.0
December 31, 1996 80.0 35.0 6.29% 26.9 5.96% 115.0
March 31, 1996 $ 0.0 $ 0.0 N/A $ 19.3 6.28% $ 51.0
</TABLE>
(1) The Company had $90.0 million in borrowings under the Credit Facility at
April 30, 1997, and therefore, had $310.0 million of remaining capacity
under the Credit Facility at April 30, 1997, which amount is expected to be
adequate for the Company's current and projected needs for short-term
financing. In addition, the Company had $85.0 million of borrowings under
informal credit lines at April 30, 1997.
(2) As applicable, includes both the Credit Facility and informal credit lines.
Weighted average amount borrowed and maximum amount borrowed are based on
week-end balances.
As further described in the Company's 1996 Report on Form 10-K, under
an August 1996 agreement, the Company transfers, to a third party, an undivided
interest in a designated pool of accounts receivable with limited recourse and
subject to a floating interest rate provision. The maximum amount allowed under
the Receivables Facility was $235.0 million until late April 1997, at which time
the Company was allowed to increase the maximum to $300.0 million, pending
completion of a formal amendment. Following is selected information concerning
the utilization of this facility.
<TABLE>
<CAPTION>
Three Months Ended March 31 or
Receivables Facility As of (1) Twelve Months Ended December 31
- -------------------------- ---------------------------------- ------------------------------------------------------------------
(dollars in millions) Collateral for Average
Transferred Receivable Net Cash Pre-tax Receivable Weighted
and Interest Inflows Financing Interest Average
Uncollected Transferred (Outflows) Cost (2) Transferred (3) Rate (3)(4)
--------------- ----------------- -------------- ------------- ------------------ ---------------
<S> <C> <C> <C> <C> <C> <C>
March 31, 1997 $ 225.0 $ 32.7 $ (10.0) $ (3.0) $ 211.6 5.36%
December 31, 1996 235.0 34.2 - (11.5) 186.9 5.41%
March 31, 1996 $ 193.3 $ 25.9 $ (41.7) $ (3.0) $ 193.4 5.56%
</TABLE>
(1) At April 30, 1997, an interest in $300.0 million of the Company's
receivables had been transferred pursuant to the Receivables Facility.
(2) See the discussion of financial statement classification following.
(3) Based on daily balances.
(4) Exclusive of a facility fee payable on the full commitment of $235.0
million ($300.0 million beginning in May 1997) which was 60 basis points
through August 21, 1995, declined to 40 basis points through March 1, 1996
and currently is 30 basis points. The rate in effect at March 31, 1997
(exclusive of the facility fee) was 5.31%.
As further described in the Company's 1996 Report on Form 10-K, the
Company adopted Statement of Financial Accounting Standards No. 125, "Accounting
for Transfers and Servicing of Financial Assets and Extinguishment of
Liabilities" ("SFAS 125") effective as of January 1, 1997 (SFAS 125 does not
allow retroactive application). Therefore, for periods prior to January 1, 1997,
(1) amounts transferred pursuant to the Receivables Facility are included with
"Cash Flows From Operating Activities" in the Company's Statement of
Consolidated Cash Flows, (2) receivables transferred pursuant to the Receivables
Facility are deducted from "Accounts and notes receivable, principally customer"
in the Company's Consolidated Balance Sheet and (3) the costs associated with
utilization of the Receivables Facility are reported as "Loss on sale of
accounts receivable", a component of "Other, net", included under "Other
(Income) and Deductions" in the Company's Statement of Consolidated Income.
Subsequent to January 1, 1997, (1) amounts transferred pursuant to the
Receivables Facility are included with "Cash Flows from Financing Activities" in
the Company's Statement of Consolidated Cash Flows, (2) amounts received
pursuant to the facility are not deducted from "Accounts and notes receivable,
principally customer" in the Company's Consolidated Balance Sheet but, rather,
such amounts are reported as short-term debt, and (3) the costs associated with
utilization of the Receivables Facility are included with "Interest expense,
net" in the Company's Statement of Consolidated Income.
As described in the Company's 1996 Report on Form 10-K, certain of the
Company's cash balances reflect credit balances to the extent that checks
written have not yet been presented for payment. Such balances are included with
"Accounts payable, principally trade" in the Company's Consolidated Balance
Sheet, and changes in such balances are reported as "Increase (decrease) in
overdrafts" in the Company's Statement of Consolidated Cash Flows.
Long-Term Financing
As further discussed in the Company's 1996 Report on Form 10-K, the
Company's long-term financing historically has been obtained through the
issuance of common stock, preferred stock, unsecured debentures and notes (the
Company is precluded under an indenture from issuing mortgage debt), bank term
loans and, recently, Trust Preferred Securities.
Following is a discussion of recent and planned financing activities.
The Company made debt reacquisitions and retirements totaling $5.5
million and $77.7 million in the first quarter of 1997 and 1996, respectively,
see Note C of the accompanying Notes to Consolidated Financial Statements. In
April 1997, the Company retired, at maturity, $225.0 million principal amount of
its 9.875% Notes, principally utilizing additional borrowings under the
Company's Receivables Facility and its Credit Facility (each as described
elsewhere herein). As described in the Company's 1996 Report on Form 10-K, the
Company has elected to utilize a smaller, shorter-term debt instrument for this
refinancing principally due to the pending merger with Houston Industries
Incorporated, see "Merger With Houston Industries" elsewhere herein. The Company
is in the process of obtaining an unsecured bank term loan ("the Pending Term
Loan") in the amount of $150.0 million and with a term of 18 months from the
date of closing. The Company currently expects that the Pending Term Loan will
carry a floating interest rate based on three-month LIBOR, will allow prepayment
without penalty and will close in May 1997.
As more fully discussed in the Company's 1996 report on Form 10-K, the
Company enters into interest rate swaps in which, in general, one party pays a
fixed rate on the notional amount while the other party pays a LIBOR-based rate
for the purposes of (1) effectively fixing the interest rate on debt expected to
be issued for refunding purposes and (2) adjusting the amount of its overall
debt portfolio which is exposed to market interest rate fluctuations. The effect
of these swaps (none of which are leveraged) was to decrease the Company's
interest expense by $0.3 million and $0.8 million for the three months ended
March 31, 1997 and 1996, respectively. Following is selected information on the
Company's portfolio of interest rate swaps at March 31, 1997:
<PAGE>
<TABLE>
<CAPTION>
Interest Rate Swap Portfolio at March 31, 1997 (1)
- --------------------------------------------------------------------
(dollars in millions) Estimated
Notional Period Interest Rate Market
Initiated Amount Covered Fixed/Floating (2) Value (3)
- ----------------------- ------------ -------------------------- --------------------- ------------
<S> <C> <C> <C> <C>
February 1996 $ 50.0 Mar. 1996 - Jan. 1998 4.76%/6.00% $ 0.5
February 1996 50.0 Jun. 1996 - Dec. 1997 4.71%/5.94% 0.4
March 1997 (4) 75.0 May 1997 - Dec. 1998 6.47%/6.41% (0.1)
March 1997 (4) 75.0 May 1997 - Dec. 1998 6.43%/6.41% -
------------ ------------
Totals $ 250.0 $ 0.8
============ ============
</TABLE>
(1) All swaps outstanding at March 31, 1997 were entered into for the purpose
of reducing the Company's exposure to fluctuations in market interest
rates.
(2) In each case, the Company is the fixed-price payor. The floating rate is
estimated as of March 31, 1997.
(3) Represents the estimated amount which would have been realized upon
termination of the swap at March 31, 1997.
(4) Due, in part, to the increase in floating interest rate exposure which will
result from amounts outstanding under the Pending Term Loan as discussed
preceding, in March 1997, the Company entered into incremental interest
rate swaps with a total notional amount of $150.0 million. These swaps
cover the period from May 1, 1997 to December 1, 1998 and require the
Company to pay an average fixed rate of approximately 6.45%, while the
counterparties (commercial banks) pay a rate based on 3-month LIBOR.
As discussed in the Company's 1996 Report on Form 10-K, in March 1997,
the Company closed out the $200.0 million of swaps which had been serving as
hedges of its anticipated April 1997 debt refinancing, receiving cash proceeds
of approximately $8.7 million. Based on the Company's expected issuance of the
Pending Term Loan for $150.0 million (as discussed preceding), approximately
$1.0 million of such proceeds will serve to reduce the effective interest rate
on the debt to be issued, and the balance was credited to earnings in March
1997, reported as a component of "Other, net" in the Company's Statement of
Consolidated Income.
Other Financing Activities
The Company received cash proceeds from sales of its common stock
pursuant to its Direct Stock Purchase Plan ("the DSPP") of approximately $2.8
million during the first quarter of 1996. Sales of stock pursuant to the DSPP
have been suspended as a result of the pending merger with Houston Industries,
see "Merger With Houston Industries" elsewhere herein. The Company paid cash
common dividends of $9.6 million and $8.7 million during the first quarters of
1997 and 1996, respectively, and declared an additional common dividend in May
1997, see "Dividend Declaration" under "Recent Developments" elsewhere herein.
The Company paid cash preferred dividends of $2.0 million during the first
quarter of 1996. As further discussed in the Company's 1996 Report on Form 10-K,
the Company's $3.00 Convertible Exchangeable Preferred Stock, Series A was
exchanged in June 1996 for the Company's 6% Convertible Subordinated Debentures
due 2012.
Debt and Dividend Limitations
As further discussed in the Company's 1996 Report on Form 10-K, the
Credit Facility contains a provision which requires the Company to maintain a
minimum level of total stockholders' equity, as well as placing a limitation of
(1) $2,055 million on total debt (unless the ratio of total debt to
capitalization is less than or equal to 60%) and (2) $200.0 million on the
amount of outstanding long-term debt which may be retired in advance of its
maturity using funds borrowed under the Credit Facility. Certain of the
Company's other financial arrangements contain similar provisions. Based on
these restrictions, at March 31, 1997, the Company had incremental debt capacity
of $354.9 million and, while the Company is not required to calculate and apply
the stockholders' equity limitation on an interim basis, if it were applied at
March 31, 1997, the Company would have had incremental dividend capacity of
$246.9 million.
COMMITMENTS
Leases. As described in the Company's 1996 Report on Form 10-K, the
Company has commitments under certain of its leasing arrangements.
Capital Expenditures. The Company had capital commitments of less than
$15.0 million at March 31, 1997, which projects are expected to be funded
through cash provided by operations and/or incremental borrowings, see "Net Cash
Flows from Investing Activities" under "Liquidity and Capital Resources"
elsewhere herein. As described in the Company's 1996 Report on Form 10-K and
under "Recent Developments" elsewhere herein, the Company expects to participate
in the construction of several distribution systems in Colombia. While
construction of these facilities has not yet begun and contracts for such
construction have not been awarded, the Company will be required to fund certain
amounts in order to maintain its current ownership interest.
Transportation Agreement. As further discussed in the Company's 1996
Report on Form 10-K, the Company has an agreement with ANR Pipeline Company
("ANR") pursuant to which the Company (1) currently retains $41.0 million
previously advanced by ANR, (2) provides 130 MMcf/day of capacity in certain of
the Company's transportation facilities to ANR and (3) is committed to refund
$5.0 million and $36.0 million to ANR in 2003 and 2005, respectively, in
exchange for ANR's release of 30 MMcf/day and 100 MMcf/day, respectively, of
such capacity.
CONTINGENCIES
Letters of Credit. At March 31, 1997, the Company was obligated for
approximately $34.7 million under letters of credit which are incidental to its
ordinary business operations.
Indemnity Provisions. As discussed in the Company's 1996 Report on
Form 10-K, the Company has obligations under the indemnification provisions
of certain sale agreements.
Sale of Receivables. Certain of the Company's receivables are
collateral for amounts received pursuant to the Receivables Facility, see "Net
Cash Flows from Financing Activities" under "Liquidity and Capital Resources"
elsewhere herein.
Gas Contract Issues. As discussed in the Company's 1996 Report on Form
10-K, the Company is a party to certain claims involving, and has certain
commitments under, its gas purchase contracts. The nature of the Company's
natural gas marketing business is such that, in general, and particularly during
periods of production interruptions, delivery curtailments and shortages of
pipeline capacity, disputes arise as to compliance with terms of
purchase/delivery commitments and related pricing provisions. While certain of
these disputes are not resolved for extended periods of time, the Company
believes that it has adequately reserved for any such amounts in dispute which
may ultimately not be resolved in its favor.
Credit Risk and Off-Balance-Sheet Risk. As discussed in the Company's
1996 Report on Form 10-K, the Company has off-balance-sheet risk as a result of
(1) its interest rate swaps, see "Net Cash Flows from Financing Activities"
elsewhere herein and (2) its natural gas risk management activities, see "Energy
Marketing and Gathering" under "Material Changes in the Results of Operations"
elsewhere herein.
Litigation. The Company is a party to litigation which arises in
the normal course of business, see "Legal Proceedings" elsewhere herein.
Environmental. As more fully described in the Company's 1996 Report on
Form 10-K, the Company is currently working with the Minnesota Pollution Control
Agency regarding the remediation of several sites on which gas was manufactured
from the late 1800's to approximately 1960. The Company has made an accrual for
its estimate of the costs of remediation (undiscounted and without regard to
potential third-party recoveries) and, based upon discussions to date and prior
decisions by regulators in the relevant jurisdictions, the Company continues to
believe that it will be allowed substantial recovery of these costs through its
regulated rates.
In addition, the Company has identified sites with possible mercury
contamination based on the type of facilities located on these sites. The
Company has not confirmed the existence of contamination at these sites, nor has
any federal, state or local governmental agency imposed on the Company an
obligation to investigate or remediate existing or potential mercury
contamination. To the extent that any compliance costs are ultimately identified
and quantified, the Company will provide an appropriate accrual and, to the
extent justified based on the circumstances within each of the Company's
regulatory jurisdictions, set up regulatory assets in anticipation of recovery
through the ratemaking process.
On October 24, 1994, the United States Environmental Protection Agency
advised MRT that it had been named a potentially responsible party under federal
law with respect to a landfill site in West Memphis, Arkansas, see "Legal
Proceedings" elsewhere herein.
On December 18, 1995, the Louisiana Department of Environmental Quality
advised the Company that it had been named a potentially responsible party under
state law with respect to a hazardous substance site in Shreveport, Louisiana,
see "Legal Proceedings" elsewhere herein.
While the nature of environmental contingencies makes complete
evaluation impractical, the Company is currently aware of no other environmental
matter which could reasonably be expected to have a material impact on its
results of operations, financial position or cash flows.
<PAGE>
Part II. Other Information
Item 1. Legal Proceedings
On August 14, 1996, an action styled Shaw vs. NorAm Energy Corp., et
al. was filed in the District Court of Harris County, Texas by a purported NorAm
stockholder against the Company, certain of its officers and directors and
Houston Industries to enjoin the merger between the Company and Houston
Industries (see Note B) or to rescind such merger and/or to recover damages in
the event that the Transaction is consummated. The complaint alleges, among
other things, that the merger consideration is inadequate, the Company's Board
of Directors breached its fiduciary duties and that Houston Industries aided and
abetted such breaches of fiduciary duties. In addition, the plaintiff seeks
certification as a class action. The Company believes that the claims are
without merit and intends to vigorously defend against the lawsuit. Management
believes that the effect on the Company's results of operations, financial
position or cash flows, if any, from the disposition of this matter will not be
material.
On October 24, 1994, the United States Environmental Protection Agency
advised MRT, a wholly-owned subsidiary of the Company, that MRT, together with a
number of other companies, had been named under federal law as a potentially
responsible party for a landfill site in West Memphis, Arkansas and may be
required to share in the cost of remediation of this site. However, considering
the information currently known about the site and the involvement of MRT, the
Company does not believe that this matter will have a material adverse effect on
the financial position, results of operations or cash flows of the Company.
On December 18, 1995, the Louisiana Department of Environmental Quality
advised the Company that the Company, through one of its subsidiaries and
together with several other unaffiliated entities, had been named under state
law as a potentially responsible party with respect to a hazardous substance
site in Shreveport, Louisiana and may be required to share in the remediation
cost, if any, of the site. However, considering the information currently known
about the site and the involvement of the Company and its subsidiaries with
respect to the site, the Company does not believe that the matter will have a
material adverse effect on the financial position, results of operations or cash
flows of the Company.
The Company is a party to litigation (other than that specifically
noted) which arises in the normal course of business. Management regularly
analyzes current information and, as necessary, provides accruals for probable
liabilities on the eventual disposition of these matters. Management believes
that the effect on the Company's results of operations, financial position or
cash flows, if any, from the disposition of these matters will not be material.
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
EX-27, Financial Data Schedule
(b) Reports on Form 8-K
None
<PAGE>
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.
NorAm Energy Corp.
(Registrant)
By: Jack W. Ellis II
Jack W. Ellis II
Vice President & Controller
Dated: May 13, 1997
<TABLE> <S> <C>
<ARTICLE> UT
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 3-MOS
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-END> MAR-31-1997
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 2,434,677
<OTHER-PROPERTY-AND-INVEST> 627,819
<TOTAL-CURRENT-ASSETS> 872,933
<TOTAL-DEFERRED-CHARGES> 55,501
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 3,990,930
<COMMON> 86,393
<CAPITAL-SURPLUS-PAID-IN> 1,004,810
<RETAINED-EARNINGS> (227,687)
<TOTAL-COMMON-STOCKHOLDERS-EQ> 864,720
0
0
<LONG-TERM-DEBT-NET> 1,047,469
<SHORT-TERM-NOTES> 87,000
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 278,000
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 1,713,741
<TOT-CAPITALIZATION-AND-LIAB> 3,990,930
<GROSS-OPERATING-REVENUE> 1,924,182
<INCOME-TAX-EXPENSE> 44,943
<OTHER-OPERATING-EXPENSES> 0
<TOTAL-OPERATING-EXPENSES> 1,778,961
<OPERATING-INCOME-LOSS> 145,221
<OTHER-INCOME-NET> 3,604
<INCOME-BEFORE-INTEREST-EXPEN> 148,825
<TOTAL-INTEREST-EXPENSE> 35,472
<NET-INCOME> 68,647
0
<EARNINGS-AVAILABLE-FOR-COMM> 68,647
<COMMON-STOCK-DIVIDENDS> 9,631
<TOTAL-INTEREST-ON-BONDS> 8,556
<CASH-FLOW-OPERATIONS> 97,600
<EPS-PRIMARY> 0.50
<EPS-DILUTED> 0.46
</TABLE>
