<PAGE> 1
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
FORM 10-Q
/X/ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly period ended MARCH 31, 1999
/ / TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Transition period from ______ to ______
Commission file number 1-1098
COLUMBIA ENERGY GROUP
(Exact Name of Registrant as Specified in its Charter)
Delaware 13-1594808
(State or other jurisdiction of (IRS Employer
incorporation or organization) Identification No.)
13880 Dulles Corner Lane, Herndon, VA 20171-4600
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code (703) 561-6000
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 ___
Indicate by check mark whether the registrant has filed all documents
and reports required to be filed by Section 12, 13 or 15(d) of the Securities
Exchange Act of 1934 subsequent to the distribution of securities under a plan
confirmed by a court. Yes X No ___
Indicate the number of shares outstanding of each of the issuer's
classes of common stock, as of the latest practicable date: Common Stock, $10
Par Value: 82,691,662 shares outstanding at April 30, 1999.
<PAGE> 2
COLUMBIA ENERGY GROUP AND SUBSIDIARIES
FORM 10-Q QUARTERLY REPORT
FOR THE QUARTER ENDED MARCH 31, 1999
TABLE OF CONTENTS
Page
PART I FINANCIAL INFORMATION
Item 1 Financial Statements
Statements of Consolidated Income 3
Consolidated Balance Sheets 4
Statements of Consolidated Cash Flows 6
Statements of Consolidated Common Stock Equity 7
Statements of Consolidated Comprehensive Income 7
Notes 8
Item 2 Management's Discussion and Analysis of
Financial Condition and Results of Operations 11
Item 3 Quantitative and Qualitative Disclosures About Market Risk 31
PART II OTHER INFORMATION
Item 1 Legal Proceedings 31
Item 2 Changes in Securities and Use of Proceeds 31
Item 3 Defaults Upon Senior Securities 31
Item 4 Submission of Matters to a Vote of Security Holders 31
Item 5 Other Information 31
Item 6 Exhibits and Reports on Form 8-K 32
Signature 33
2
<PAGE> 3
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS
Columbia Energy Group and Subsidiaries
STATEMENTS OF CONSOLIDATED INCOME (unaudited)
<TABLE>
<CAPTION>
Three Months
Ended March 31,
------------------------
1999 1998
---------- ----------
(millions, except
per share amounts)
<S> <C> <C>
NET REVENUES
Energy sales $ 2,260.2 $ 1,598.0
Less: Products purchased 1,896.9 1,219.2
---------- ----------
Gross Margin 363.3 378.8
Transportation 210.7 161.2
Production gas sales 10.4 17.4
Other 66.9 65.1
---------- ----------
Total Net Revenues 651.3 622.5
---------- ----------
OPERATING EXPENSES
Operation and maintenance 248.1 206.1
Settlement of gas supply charges (29.8) --
Depreciation and depletion 76.8 73.2
Other taxes 83.6 89.0
---------- ----------
Total Operating Expenses 378.7 368.3
---------- ----------
OPERATING INCOME 272.6 254.2
---------- ----------
OTHER INCOME (DEDUCTIONS)
Interest income and other, net 4.2 2.3
Interest expense and related charges (41.1) (41.6)
---------- ----------
Total Other Income (Deductions) (36.9) (39.3)
---------- ----------
INCOME BEFORE INCOME TAXES 235.7 214.9
Income Taxes 85.3 67.4
---------- ----------
NET INCOME $ 150.4 $ 147.5
========== ==========
BASIC EARNINGS PER SHARE OF COMMON STOCK* $ 1.81 $ 1.77
DILUTED EARNINGS PER SHARE OF COMMON STOCK* $ 1.80 $ 1.77
DIVIDENDS PAID PER SHARE OF COMMON STOCK* $ 0.20 $ 0.17
BASIC AVERAGE COMMON SHARES OUTSTANDING (thousands)* 83,244 83,259
DILUTED AVERAGE COMMON SHARES (thousands)* 83,522 83,531
</TABLE>
The accompanying Notes to Consolidated Financial Statements are an integral part
of these statements.
* All 1998 per share amounts, basic average common shares outstanding and
diluted average common shares have been restated to reflect a three-for-two
common stock split, in the form of a stock dividend, effective June 15, 1998.
3
<PAGE> 4
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
Columbia Energy Group and Subsidiaries
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
As of
-------------------------
March 31, December 31,
1999 1998
--------- ------------
(unaudited)
ASSETS (millions)
<S> <C> <C>
PROPERTY, PLANT AND EQUIPMENT
Gas utility and other plant, at original cost $7,764.3 $7,687.8
Accumulated depreciation (3,675.8) (3,592.3)
-------- --------
Net Gas Utility and Other Plant 4,088.5 4,095.5
-------- --------
Gas and oil producing properties, full cost method
United States cost center 715.6 714.1
Canadian cost center 6.4 5.0
Accumulated depletion (233.6) (225.4)
-------- --------
Net Gas and Oil Producing Properties 488.4 493.7
-------- --------
Net Property, Plant and Equipment 4,576.9 4,589.2
-------- --------
INVESTMENTS AND OTHER ASSETS 133.2 122.1
-------- --------
CURRENT ASSETS
Cash and temporary cash investments 161.3 26.3
Accounts receivable, net 1,225.8 1,004.9
Gas inventory 31.2 186.0
Other inventories - at average cost 28.0 26.8
Prepayments 102.8 115.9
Regulatory assets 60.6 59.5
Underrecovered gas costs 27.5 24.5
Deferred property taxes 57.1 80.0
Exchange gas receivable 190.7 187.4
Other 133.1 69.2
-------- --------
Total Current Assets 2,018.1 1,780.5
-------- --------
REGULATORY ASSETS 381.2 391.4
DEFERRED CHARGES 122.9 85.5
-------- --------
TOTAL ASSETS $7,232.3 $6,968.7
======== ========
</TABLE>
The accompanying Notes to Consolidated Financial Statements are an integral part
of these statements.
4
<PAGE> 5
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
Columbia Energy Group and Subsidiaries
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
As of
-------------------------
March 31, December 31,
1999 1998
--------- ------------
(unaudited)
CAPITALIZATION AND LIABILITIES (millions)
<S> <C> <C>
CAPITALIZATION
Common stock equity $2,099.3 $2,005.3
Long-term debt 2,003.1 2,003.1
-------- --------
Total Capitalization 4,102.4 4,008.4
-------- --------
CURRENT LIABILITIES
Short-term debt -- 144.8
Accounts and drafts payable 572.0 710.7
Accrued taxes 238.7 205.9
Accrued interest 58.3 17.3
Estimated rate refunds 63.7 59.2
Supplier obligations 40.7 72.4
Overrecovered gas costs 22.6 34.3
Transportation and exchange gas payable 487.8 134.2
Other 362.5 312.9
-------- --------
Total Current Liabilities 1,846.3 1,691.7
-------- --------
OTHER LIABILITIES AND DEFERRED CREDITS
Deferred income taxes, noncurrent 672.5 655.3
Investment tax credits 33.8 34.1
Postretirement benefits other than pensions 103.7 103.7
Regulatory liabilities 43.2 44.0
Deferred revenue 187.3 191.4
Other 243.1 240.1
-------- --------
Total Other Liabilities and Deferred Credits 1,283.6 1,268.6
-------- --------
TOTAL CAPITALIZATION AND LIABILITIES $7,232.3 $6,968.7
======== ========
</TABLE>
5
<PAGE> 6
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
Columbia Energy Group and Subsidiaries
STATEMENTS OF CONSOLIDATED CASH FLOWS (unaudited)
<TABLE>
<CAPTION>
Three Months
Ended March 31,
--------------------
1999 1998
------- -------
(millions)
<S> <C> <C>
OPERATING ACTIVITIES
Net income $ 150.4 $ 147.5
Adjustments for items not requiring (providing) cash:
Depreciation and depletion 76.8 73.2
Deferred income taxes 9.8 18.5
Earnings from equity investment, net of distributions (3.0) (0.5)
Other - net (31.0) (3.2)
------- -------
203.0 235.5
Change in components of working capital:
Accounts receivable (220.9) (0.8)
Gas inventory 154.8 176.0
Prepayments 13.1 12.9
Accounts payable (122.4) (52.7)
Accrued taxes 32.8 21.4
Accrued interest 41.0 36.8
Estimated rate refunds 4.5 1.9
Under/Overrecovered gas costs (14.7) 27.2
Exchange gas receivable/payable 350.3 (25.2)
Other working capital 23.8 (1.2)
------- -------
Net Cash from Operations 465.3 431.8
------- -------
INVESTMENT ACTIVITIES
Capital expenditures (87.5) (70.5)
Other investments - net (8.0) (6.9)
------- -------
Net Investment Activities (95.5) (77.4)
------- -------
FINANCING ACTIVITIES
Dividends paid (16.6) (13.8)
Issuance of common stock 0.3 2.0
Issuance (repayment) of short-term debt (144.8) (305.3)
Purchase of treasury stock (42.0) --
Other financing activities (31.7) (38.8)
------- -------
Net Financing Activities (234.8) (355.9)
------- -------
Increase (Decrease) in cash and temporary cash investments 135.0 (1.5)
Cash and temporary cash investments at beginning of year 26.3 28.7
------- -------
CASH AND TEMPORARY CASH INVESTMENTS AT MARCH 31 * $ 161.3 $ 27.2
======= =======
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest $ 1.1 $ 3.8
Cash paid for income taxes (net of refunds) $ 21.9 $ 0.6
</TABLE>
The accompanying Notes to Consolidated Financial Statements are an integral part
of these statements.
* The Corporation considers all highly liquid short-term investments to be cash
equivalents.
6
<PAGE> 7
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
Columbia Energy Group and Subsidiaries
STATEMENTS OF CONSOLIDATED COMMON STOCK EQUITY
<TABLE>
<CAPTION>
As of
------------------------
March 31, December 31,
1999 1998
--------- ------------
(unaudited)
(millions)
<S> <C> <C>
Common stock, $10 par value, authorized
100,000,000 shares, outstanding 82,689,397
and 83,511,878 shares, respectively $ 835.1 $ 835.1
Additional paid in capital 763.7 761.8
Retained earnings 543.3 409.5
Unearned employee compensation (0.6) (0.9)
Accumulated Other Comprehensive Income (0.2) (0.2)
Treasury stock, at cost (826,300 shares held as of March 31, 1999) (42.0) --
-------- --------
TOTAL COMMON STOCK EQUITY $2,099.3 $2,005.3
======== ========
</TABLE>
Columbia Energy Group and Subsidiaries
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
<TABLE>
<CAPTION>
For the period ended
------------------------
March 31, December 31,
1999 1998
--------- ------------
(unaudited)
(millions)
<S> <C> <C>
COMPREHENSIVE INCOME
Net income $ 150.4 $ 269.2
Other Comprehensive Income:
Foreign currency translation adjustment -- (0.2)
------- -------
COMPREHENSIVE INCOME $ 150.4 $ 269.0
======= =======
</TABLE>
The accompanying Notes to Consolidated Financial Statements are an integral part
of these statements.
7
<PAGE> 8
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
Columbia Energy Group and Subsidiaries
NOTES
1. Basis of Accounting Presentation
The accompanying unaudited consolidated financial statements for the
Columbia Energy Group (Columbia) reflect all normal recurring
adjustments that are necessary, in the opinion of management, to
present fairly the results of operations in accordance with generally
accepted accounting principles.
The accompanying financial statements should be read in conjunction
with the consolidated financial statements and notes thereto included
in Columbia's 1998 Annual Report on Form 10-K. Income for interim
periods may not be indicative of results for the calendar year due to
weather variations and other factors. Certain reclassifications have
been made to the 1998 financial statements to conform to the 1999
presentation.
2. Diluted Average Common Shares Computation
Financial Accounting Standards Board Statement of Financial Accounting
Standards No. 128, "Earnings Per Share" (SFAS No. 128) requires dual
presentation of basic and diluted earnings per share (EPS) by entities
with complex capital structures and also requires restatement of all
prior-period EPS data presented. Basic EPS includes no dilution and is
computed by dividing income available to common stockholders by the
weighted-average number of common shares outstanding for the period.
Diluted EPS reflects the potential dilution if certain securities are
converted into common stock.
The numerator in calculating both basic and diluted earnings per share
for each year is reported net income. The computation of diluted
average common shares follows:
<TABLE>
<CAPTION>
Three Months
Ended March 31,
-----------------
Diluted Average Common Shares Computation 1999 1998
------------------------------------------------------------------
<S> <C> <C>
Denominator (thousands)
Average common shares outstanding 83,244 83,259
Dilutive potential common shares - options 278 272
------------------------------------------------------------------
DILUTED AVERAGE COMMON SHARES 83,522 83,531
==================================================================
</TABLE>
The number of shares reflect a three-for-two common stock split, in the
form of a stock dividend, effective June 15, 1998.
8
<PAGE> 9
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
3. Business Segment Information
Columbia manages its operations in five primary business segments:
transmission and storage; distribution, exploration and production;
marketing; and propane, power generation and LNG. The following tables
provide information concerning these major business segments. Revenues
include intersegment sales to affiliated subsidiaries, which are
eliminated when consolidated. Affiliated sales are recognized on the
basis of prevailing market or regulated prices. Operating income is
derived from revenues and expenses directly associated with each
segment.
<TABLE>
<CAPTION>
Three Months
Ended March 31,
--------------------
($ in millions) 1999 1998
--------------------------------------------------------------
<S> <C> <C>
REVENUES
Transmission and Storage
Unaffiliated 164.1 148.2
Intersegment 89.2 96.7
--------------------------------------------------------------
TOTAL 253.3 244.9
--------------------------------------------------------------
Distribution
Unaffiliated 1,017.4 791.6
Intersegment 0.7 10.1
--------------------------------------------------------------
TOTAL 1,018.1 801.7
--------------------------------------------------------------
Exploration and Production
Unaffiliated 15.0 21.2
Intersegment 15.5 16.2
--------------------------------------------------------------
TOTAL 30.5 37.4
--------------------------------------------------------------
Marketing
Unaffiliated 1,321.6 856.4
Intersegment 8.0 9.0
--------------------------------------------------------------
TOTAL 1,329.6 865.4
--------------------------------------------------------------
Propane, Power Generation and LNG
Unaffiliated 40.0 29.9
Intersegment 0.3 0.3
--------------------------------------------------------------
TOTAL 40.3 30.2
--------------------------------------------------------------
Adjustments and eliminations
Intersegment (113.7) (132.3)
--------------------------------------------------------------
TOTAL (113.7) (132.3)
--------------------------------------------------------------
CONSOLIDATED 2,558.1 1,847.3
--------------------------------------------------------------
--------------------------------------------------------------
OPERATING INCOME (LOSS)
Transmission and Storage 144.2 117.8
Distribution 130.2 120.1
Exploration and Production 5.6 14.4
Marketing (21.5) (5.5)
Propane, Power Generation and LNG 9.1 7.5
Corporate 5.0 (0.1)
--------------------------------------------------------------
CONSOLIDATED 272.6 254.2
==============================================================
</TABLE>
9
<PAGE> 10
PART I - FINANCIAL INFORMATION
ITEM 1 - FINANCIAL STATEMENTS (CONTINUED)
4. Treasury Stock
In February 1999, Columbia's board of directors approved a repurchase
program for up to $100 million of its common stock, through February
29, 2000. The repurchase program authorizes Columbia to make purchases
in the open market or otherwise. The timing and terms of purchases, and
the number of shares actually purchased, is determined by management
based on market conditions and other factors. Purchased shares are held
in treasury and are available for general corporate purposes or resale
at a future date, or may be retired. Treasury stock purchases are
accounted for under the cost method, whereby the cost of the acquired
stock is recorded as treasury stock. As of March 31, 1999, Columbia
purchased 826,300 common shares at a cost of $42 million.
5. Risk Management Activities
Columbia has adopted a policy that provides for commodity trading
activities to help ensure stable cash flow, favorable prices and
margins as well as to help capture any long-term increases in value.
Effective January 1, 1999, Columbia adopted Financial Accounting
Standards Board Emerging Issues Task Force Issue No. 98-10, "Accounting
for Contracts Involved in Energy Trading and Risk Management
Activities" (EITF 98-10). The net impact of applying EITF 98-10 was
immaterial to the consolidated financial statements for the three
months ended March 31, 1999.
6. Bankruptcy Matters
On November 28, 1995, Columbia and its wholly-owned subsidiary,
Columbia Gas Transmission Corporation (Columbia Transmission) emerged
from Chapter 11 protection of the United States Bankruptcy Code under
the jurisdiction of the United States Bankruptcy Court for the District
of Delaware (Bankruptcy Court). Both Columbia and Columbia Transmission
had operated under Chapter 11 protection from July 31, 1991, until
emergence.
In July 1998, the Bankruptcy Court, granting a motion by Columbia
Transmission, entered an Order allowing the claim of the New Bremen
Corporation (New Bremen) in accordance with the Claims Mediator's
Report and Recommendations and the decision of the U.S. 5th Circuit
Court of Appeals. In August 1998, New Bremen filed a notice of appeal
of this order to the U.S. District Court for the District of Delaware.
This litigation was the last remaining producer claim in Columbia
Transmission's bankruptcy proceeding. During the first quarter of 1999,
Columbia Transmission reached a settlement with New Bremen. The
improvement to Columbia's first quarter 1999 consolidated net income
was $20.6 million. The settlement was approved by the Bankruptcy Court
on April 12, 1999, and on April 26, 1999, Columbia Transmission
distributed the producer holdback amounts in accordance with its Plan
of Reorganization and the New Bremen settlement.
10
<PAGE> 11
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
OPERATING INCOME (LOSS) BY SEGMENT
<TABLE>
<CAPTION>
Three Months
Ended March 31,
------------------------
1999 1998
------- -------
(millions)
<S> <C> <C>
Transmission and Storage $ 144.2 $ 117.8
Distribution 130.2 120.1
Exploration and Production 5.6 14.4
Marketing (21.5) (5.5)
Propane, Power Generation and LNG 9.1 7.5
Corporate 5.0 (0.1)
------- -------
CONSOLIDATED $ 272.6 $ 254.2
======= =======
</TABLE>
DEGREE DAYS (DISTRIBUTION SERVICE TERRITORY)
<TABLE>
<CAPTION>
Three Months
Ended March 31,
----------------------
1999 1998
------ ------
<S> <C> <C>
Actual 2,778 2,319
Normal 2,947 2,947
% Colder (warmer) than normal (6) (21)
% Colder (warmer) than prior period 20 (14)
</TABLE>
11
<PAGE> 12
PART I - FINANCIAL INFORMATION
ITEM 2- MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
CONSOLIDATED RESULTS
Forward-Looking Statements
The Management's Discussion and Analysis, including statements regarding market
risk sensitive instruments and in the section "Impact of Year 2000 on Computer
and Other Systems," contains "forward-looking statements," within the meaning of
Section 27A of the Securities Act of 1933, as amended, and Section 21E of the
Securities Exchange Act of 1934, as amended. Investors and prospective investors
should understand that many factors govern whether any forward-looking statement
contained herein will be or can be achieved. Any one of those factors could
cause actual results to differ materially from those projected. These
forward-looking statements include, but are not limited to, statements
concerning Columbia's plans, proposed acquisitions, objectives, expected
performance, expenditures and recovery of expenditures through rates, stated on
either a consolidated or segment basis, and any and all underlying assumptions
and other statements that are other than statements of historical fact. From
time to time, Columbia may publish or otherwise make available forward-looking
statements of this nature. All such subsequent forward-looking statements,
whether written or oral and whether made by or on behalf of Columbia, are also
expressly qualified by these cautionary statements. All forward-looking
statements are based on assumptions that management believes to be reasonable;
however, there can be no assurance that actual results will not differ
materially. Realization of Columbia's objectives and expected performance is
subject to a wide range of risks and can be adversely affected by, among other
things, competition, weather, fluctuations in supply and demand for energy
commodities, successful consummation of proposed acquisitions, actual operating
experience of acquired assets, our ability to integrate acquired operations into
our operations, impact of the year 2000 on computer, operating and other
systems, the regulatory process, regulatory and legislative changes as well as
changes in general economic, capital and commodity market conditions, many of
which are beyond the control of Columbia. In addition, the relative
contributions to profitability by each segment, and the assumptions underlying
the forward-looking statements relating thereto, may change over time. With
respect to Columbia's year 2000 program, the dates on which Columbia believes it
will be completed are based on management's best estimates, which were derived
utilizing numerous assumptions of future events. However, there can be no
guarantee that these estimates will be achieved, or that there will not be a
delay in, or increased costs associated with, the implementation of the year
2000 program. Specific factors that might cause differences between the
estimates and actual results include, but are not limited to, the availability
and cost of personnel trained in these areas, the ability to timely locate and
correct all relevant computer codes for both information technology (IT) and
non-IT systems, the nature and amount of programming and testing required to
upgrade or replace IT and non-IT systems, timely responses to, and corrections
by, third-parties and suppliers, the ability to implement interfaces between,
and among, IT and non-IT systems for which remediation or an upgrade is
performed, the nature and amount of testing, verification and reporting required
by relevant government regulatory authorities, including federal and state
utility regulatory bodies, and other similar uncertainties.
With respect to any references made to ratings assigned to Columbia's debt
securities, there can be no assurance that Columbia will be successful in
maintaining its credit quality, or that such credit ratings will continue for
any given period of time, or that they will not be revised downward or withdrawn
entirely by the rating agencies. Credit ratings reflect only the views of the
rating agencies, whose methodology and the significance of their ratings may be
obtained from them.
First Quarter Results
Net Income
Columbia reported first quarter 1999 net income of $150.4 million, or $1.81 per
share, up $2.9 million, or $0.04 per share, from $147.5 million, or $1.77 per
share, for the first quarter of 1998. This increase
12
<PAGE> 13
PART I - FINANCIAL INFORMATION
ITEM 2- MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
CONSOLIDATED RESULTS (CONTINUED)
reflected 1999 first quarter weather that was 20 percent colder than the record
warm weather in the same period last year; however, the first quarter of 1999
was still six percent warmer than normal. This improvement was tempered by the
impact of weak natural gas prices that reduced the price received for gas
production and depressed trading results, and higher costs related to
investments and additional staffing in the marketing segment.
The first quarters of both 1999 and 1998 included one-time items, which were
similar in magnitude. In 1999, Columbia reached a settlement on the last
remaining producer issue stemming from Columbia's bankruptcy proceedings that
concluded in 1995, which improved net income $20.6 million. By order dated April
12, 1999, the bankruptcy court approved this settlement. In 1998, income
benefited from a $15 million after-tax reduction in postretirement benefit costs
that reflected the purchase of insurance for a portion of those liabilities. In
addition, the implementation of state tax planning initiatives increased 1998's
first quarter net income by $10 million.
Revenues
Total consolidated net revenues (operating revenues less associated products
purchased costs) for the three months ended March 31, 1999, were $651.3 million,
a $28.8 million increase over the same period last year primarily reflecting
increased net revenues from transportation services for the distribution and
transmission segments. This improvement was tempered by lower prices received
for gas production and weaker margins in the marketing segment.
Expenses
Operating expenses for the first quarter of 1999 were $378.7 million, an
increase of $10.4 million over the same period last year. The settlement of gas
supply charges reduced operating expenses by $29.8 million reflecting the
bankruptcy-related producer settlement mentioned above. Operation and
maintenance expense increased $42 million when compared to the first quarter of
1998. Much of this period-to-period change is attributable to a $23.1 million
favorable adjustment recorded last year for a reduction in postretirement
benefit costs, mentioned above, and higher costs incurred by the marketing
segment this year for additional staffing and building its infrastructure. Also
increasing operation and maintenance expense were additional costs associated
with the increased propane operations that resulted from acquisitions completed
in the second half of 1998.
Other Income (Deductions)
Other Income (Deductions), which includes interest income and other interest
expense, reduced income by $36.9 million for the first three months of 1999
compared to a reduction to income of $39.3 million in the same period last year.
Income increased $1.9 million, primarily due to a gain on the sale of Columbia
Energy Resources, Inc.'s (Columbia Resources) surface coal property for $2.9
million, partially offset by lower interest income on temporary investments.
Interest expense for the first three months of 1999 was essentially unchanged
from the same period last year.
Income Taxes
For the three months ended March 31, 1999, income tax expense of $85.3 million
increased $17.9 million compared with the same period last year. The
period-to-period increase primarily reflected a 1998 reduction in the effective
state income tax rate due to the implementation by Columbia of tax planning
initiatives, as well as the higher first quarter 1999 pre-tax income.
Liquidity and Capital Resources
A significant portion of Columbia's operations, most notably in the distribution
segment, is subject to
13
<PAGE> 14
PART I - FINANCIAL INFORMATION
ITEM 2- MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
CONSOLIDATED RESULTS (CONTINUED)
seasonal fluctuations in cash flow. During the heating season, which is
primarily from November through March, cash receipts from sales and
transportation services typically exceed cash requirements. Conversely, during
the remainder of the year, cash on hand, together with external short-term and
long-term financing, as needed, is used to purchase gas to place in storage for
heating season deliveries, perform necessary maintenance of facilities, make
capital improvements in plant and expand service.
Net cash from operations for the first three months of 1999 was $465.3 million,
an increase of $33.5 million over the same period last year. This increase
primarily reflects working capital changes, which include a decrease in the
overrecovery position primarily reflecting higher gas prices in the current
period compared to the same period in 1998. The recovery of gas costs in the
distribution subsidiaries' rates is provided for under the current regulatory
process.
Columbia satisfies its liquidity requirements primarily through internally
generated funds and from the sale of commercial paper, which is supported by the
use of two unsecured bank revolving credit facilities that total $1.35 billion
(Credit Facilities). The Credit Facilities consist of a $450 million 364-day
revolving credit facility, with a one-year term loan option, that expires in
March 2000 and a $900 million five-year revolving credit facility that expires
in March 2003 and provides for the issuance of up to $300 million of letters of
credit.
Interest rates on borrowings under the Credit Facilities are based upon
the London Interbank Offered Rate, Certificate of Deposit rates or other
short-term interest rates. In addition, the 364-day facility has a utilization
fee if borrowings exceed a certain level. The interest rate margins and
facility fee on the commitment amounts are based on Columbia's public debt
ratings. In 1998, Moody's Investors Service, Inc. (Moody's) and Fitch Investors
Service (Fitch) each upgraded their rating of Columbia's long-term debt to A3
and A, respectively. Columbia's long-term debt rating is BBB+ by Standard &
Poor's Ratings Group (S&P). Under the Credit Facilities, higher debt ratings
result in lower facility fees and interest rate margins on borrowings.
Columbia's commercial paper ratings are F-1 by Fitch, P-2 by Moody's and A-2 by
S&P.
As of March 31, 1998, Columbia had approximately $127.2 million of letters of
credit issued, of which $48.2 million were issued under the Credit Facilities.
At the end of the first quarter of 1999, Columbia did not have any commercial
paper outstanding.
During 1998, Columbia entered into fixed-to-floating interest rate swap
agreements to modify the interest characteristics of $300 million of its
outstanding long-term debt. As a result of these transactions, that portion of
Columbia's long-term debt is now subject to fluctuations in interest rates. This
allows Columbia to benefit from a lower interest rate environment. In order to
maintain a balance between fixed and floating interest rates, Columbia is
targeting average floating rate debt exposure for 10-20% of its outstanding
long-term debt.
Columbia has an effective shelf registration statement on file with the U.S.
Securities and Exchange Commission for the issuance of up to $1 billion in
aggregate of debentures, common stock or preferred stock in one or more series.
Currently, Columbia has remaining $750 million available under the shelf
registration.
At its February 1999 meeting, Columbia's Board of Directors authorized the
purchase of up to $100 million of Columbia's common stock through February 29,
2000, in the open market or otherwise. The
14
<PAGE> 15
PART I - FINANCIAL INFORMATION
ITEM 2- MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
CONSOLIDATED RESULTS (CONTINUED)
source of funds for repurchases would consist of available funds or short-term
borrowings. Through March 31, 1999, 826,300 common shares have been repurchased
under this program at a cost of $42 million. The timing and terms of additional
purchases, and the number of shares actually purchased, will be determined by
management based on market conditions and other factors. Purchased shares will
be held in treasury to be made available for general corporate purposes, or
resale at a future date, or they may be retired.
Management believes that its sources of funding are sufficient to meet
short-term and long-term liquidity needs.
Proposed Acquisition
On April 18, 1999, Columbia announced that it was proposing a negotiated merger
transaction between Columbia and Consolidated Natural Gas Company (CNG). After
providing information requested by CNG, Columbia sent a definitive merger
agreement to CNG for consideration of CNG's Board of Directors. On May 11, 1999,
CNG's Board of Directors voted to reject Columbia's proposal in favor of a
revised offer for a transaction with Dominion Resources, Inc. and Columbia
subsequently withdrew its offer. On May 12, 1999, Columbia confirmed that it
does not intend to pursue a further offer to acquire CNG.
Presentation of Segment Information
Columbia revised its presentation of primary business segment information
beginning with the reporting of second quarter results for 1998. Marketing
operations are now reported in a separate segment rather than the former
marketing, propane and power generation segment. Columbia LNG Corporation's
results are now reported in the propane, power generation and LNG segment,
rather than in the transmission and storage segment. The results for the first
quarter of 1998 have been restated to reflect this change.
Market Risk Exposure
Subsidiaries in Columbia's exploration and production, marketing and propane
operations are exposed to market risk due primarily to fluctuations in commodity
prices. In order to help minimize this risk, Columbia has adopted a policy that
provides for commodity trading activities to help ensure stable cash flow,
favorable prices and margins as well as to help capture any long-term increases
in value. Financial instruments authorized for use by Columbia for commodity
trading include futures, swaps and options. Columbia Energy Services Corporation
(Columbia Energy Services) utilizes financial instruments to help assure
adequate margins on the purchase and resale of natural gas and electric power.
Columbia Resources also utilizes financial instruments to fix prices for a
portion of its future production volumes. These positions of Columbia Resources
are hedged in the marketplace through Columbia Energy Services. Columbia Propane
Corporation (Columbia Propane) utilizes financial instruments to help protect
the value of its inventories.
In the third quarter of 1998, Columbia's policy was expanded to allow open
trading positions in electric power for its marketing segment operations to take
advantage of market information or strategic opportunities related to
electricity commodity prices and basis. Also in the third quarter, trading
activity in weather derivatives was authorized. Positions in natural gas,
electric power and weather derivatives are controlled within predetermined
limits as provided by Columbia's senior management. Columbia's policy prohibits
any Columbia subsidiary from entering into trading positions that are not
effectively connected with its business. The risks associated with these trading
activities are managed consistent with policies approved by Columbia's Board of
Directors. Market risks are monitored by an independent risk control group
operating separately from the area that creates or actively manages these risk
15
<PAGE> 16
PART I - FINANCIAL INFORMATION
ITEM 2- MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
CONSOLIDATED RESULTS (CONTINUED)
exposures to ensure compliance with Columbia's stated risk management policies.
Effective January 1, 1999, Columbia adopted Financial Accounting Standards Board
Emerging Issues Task Force's recently issued Statement 98-10.
Columbia measures the market risk in its portfolios on a daily basis and employs
multiple risk control mechanisms to mitigate market risk including value-at-risk
measures using a variance/covariance methodology and volumetric limits.
Columbia also utilizes fixed-to-floating interest rate swap agreements to modify
the interest characteristics of a portion of its outstanding long-term debt. As
a result of these transactions, that portion of Columbia's long-term debt is now
subject to fluctuations in interest rates.
Impact of Year 2000 on Computer and Other Systems
The Year 2000 issue is a worldwide concern because many existing computer
programs and certain computer hardware were initially designed without
considering the impact of the change to the Year 2000. If not corrected, certain
computer, operating and other systems could fail or create erroneous results.
Columbia is evaluating its IT and non-IT systems to determine if they are Year
2000 compliant and, if these systems are not Year 2000 compliant, what
corrective action is necessary. IT and non-IT systems that are currently being
identified, tested and, as necessary, corrected or replaced with compliant
systems include: 1) mission critical processes that relate to the safety or
dependability of Columbia's natural gas delivery system and other core business
operations; 2) customer billing, vendor payment, shareholder records and payroll
systems; and 3) other processes relevant to Columbia's continued operations.
Embedded chips and other non-IT hardware that are found to not be Year 2000
compliant are being replaced or upgraded as appropriate. To ensure timely
completion of all phases of the Year 2000 project, Columbia is utilizing
external consultants with specific Year 2000 expertise on certain aspects of the
project.
Columbia's Year 2000 program is divided into phases that provide for the timely
assessment, remediation and testing of IT and non-IT systems as appropriate. The
assessment phase, which was completed at the end of 1998, covers the inventory
of systems and the determination as to where potential problems may exist. If a
system can not be determined to be either compliant or not date sensitive, it is
deemed non-compliant and scheduled for inclusion in the remediation/testing
phases. The remediation phase was for the correction of any Year 2000 compliance
issues through repair or replacement and was substantially completed for IT
systems and non-IT systems as of the date of this report. The testing phase,
which is estimated to be approximately 86% and 50% complete for IT and non-IT
systems, respectively, is designed to provide assurance that the remediation
effort has been successful. Critical devices are tested regardless of whether a
manufacturer/vendor has indicated that the device was Year 2000 compliant.
Columbia currently has in place general contingency plans in the event that a
computer system, facility or process fails; however, Columbia continues its
evaluation of the need for special contingency plans in the event that a Year
2000 problem should arise in spite of Columbia's efforts to ensure Year 2000
compliance. Where appropriate, specific Year 2000 contingency plans are being
developed for those systems that are essential to Columbia's ongoing businesses.
Contingency plans involve having alternate suppliers, processes or personnel on
stand-by for essential processes. Columbia's planning for the Year 2000
contingency phase for mission critical processes began on January 1, 1999.
16
<PAGE> 17
PART I - FINANCIAL INFORMATION
ITEM 2- MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
CONSOLIDATED RESULTS (CONTINUED)
For the overall Year 2000 project, the assessment phase is complete. The
remediation phase is substantially complete and the testing phase is anticipated
to be completed by the end of the second quarter of 1999. Any Year 2000 specific
contingency plans that may be necessary are scheduled to be completed by the end
of July 1999.
During Columbia's evaluation of a potential acquisition, it performs a Year 2000
readiness review to determine that the company's systems either are or will be
Year 2000 compliant in a timely manner.
Another area of concern is Columbia's exposure from third parties that may not
be Year 2000 compliant. Columbia continues the process of contacting third
parties with which it conducts business to obtain assurance that they will be
Year 2000 compliant, utilizing letters and, where appropriate, questionnaires.
Columbia has mailed letters to nearly all of its significant vendors and service
providers and has verbally communicated with many of those strategic customers
to determine whether or not interfaces with such entities are vulnerable to Year
2000 problems and whether the products and services purchased from or by such
entities are Year 2000 compliant. Columbia has received responses from a large
number of these third parties with many of the companies indicating that they
expect to address all of their significant Year 2000 issues on a timely basis. A
follow-up mailing to significant vendors and service providers that have not
responded, or whose responses were deemed unsatisfactory by Columbia, is
currently underway.
The total estimated cost of assessing, testing and remediating Columbia's IT and
non-IT systems for Year 2000 compliance, along with the cost of developing
contingency plans, is approximately $16 million. The bulk of Columbia's Year
2000 project budget has been and will be applied to the remediation and testing
phases. This estimate does not include costs that will be incurred by Columbia
related to the acquisitions discussed elsewhere in this report that are expected
to close during 1999, however, these incremental Year 2000 costs are not
expected to be material. The estimated total cost of the Year 2000 project
represents management's assessment, based on information currently available,
scope of the project, work already completed and estimated remaining work. The
expenditures necessary to become Year 2000 compliant will be satisfied through
Columbia's cash flow from operations.
As part of its normal operations, Columbia continuously operates in a
safety-conscious, high-reliability environment and has numerous back-up systems
in place. As a result of the extensive planning that has been incorporated into
Columbia's current contingency plans and the Year 2000 project, management
believes that the most reasonably likely worst case Year 2000 scenario would
involve minor failures that were not detected and corrected during the project.
These failures should not be of the type that could result in the disruption of
services and will, in all likelihood, be corrected quickly. However, the failure
of Columbia or a key third party supplier to correct a material Year 2000
problem could result in an interruption in, or a failure of, certain normal
business activities or operations including Columbia's ability to deliver
energy. For such a failure to be material, numerous back-up systems or processes
would also have to fail. For example, an interruption in electric service along
Columbia's pipeline system could impact the operation of one or more compressor
stations or other field facilities and equipment. This impact, if coupled with
the failure of critical back-up systems and processes, could materially and
adversely affect Columbia's operations, liquidity and financial condition. Due
to the general uncertainty inherent in the Year 2000 issue, due in part to the
uncertainty of the Year 2000 readiness of third party suppliers and customers,
Columbia is unable to determine at this time whether the consequences of any
likely Year 2000 failures will have a material impact on Columbia's operations,
liquidity or financial condition.
17
<PAGE> 18
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
TRANSMISSION AND STORAGE OPERATIONS
<TABLE>
<CAPTION>
Three Months
Ended March 31,
------------------------
1999 1998
------- -------
<S> <C> <C>
OPERATING REVENUES
Transportation revenues $ 182.4 $ 180.1
Storage revenues 50.3 46.6
Other revenues 20.6 18.2
------- -------
Total Operating Revenues 253.3 244.9
------- -------
OPERATING EXPENSES
Operation and maintenance 96.9 85.5
Settlement of gas supply charges (29.8) --
Depreciation 26.7 26.0
Other taxes 15.3 15.6
------- -------
Total Operating Expenses 109.1 127.1
------- -------
OPERATING INCOME $ 144.2 $ 117.8
======= =======
THROUGHPUT (Bcf)
Transportation
Columbia Transmission
Market area 394.0 356.7
Columbia Gulf
Mainline 147.4 130.7
Short-haul 50.6 62.2
Intrasegment eliminations (138.7) (125.0)
------- -------
Total Throughput 453.3 424.6
======= =======
</TABLE>
18
<PAGE> 19
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
TRANSMISSION AND STORAGE OPERATIONS (CONTINUED)
Mainline '99
Columbia Gulf Transmission Company (Columbia Gulf) filed an application with the
Federal Energy Regulatory Commission (FERC) in June 1998, for authority to
increase the maximum certificated capacity of its mainline facilities. The
expansion project, referred to as Mainline '99, will increase Columbia Gulf's
certificated capacity to nearly 2.2 billion cubic feet (Bcf) per day by
replacing certain compressor units and increasing the horsepower capacity of
other compressor stations. Various shippers contracted for the additional
service through an open bidding process held in late 1997 and early 1998. On
February 10, 1999, the FERC issued an order approving Columbia Gulf's June 1998
filing. Construction commenced on March 3, 1999. On March 12, 1999, requests for
rehearing of the FERC order were filed by three parties.
Columbia Gas Transmission Corporation's (Columbia Transmission's) Phase II Rate
Proceeding
Columbia Transmission's rate case settlement, approved by the FERC in
April 1997, provided for a hearing to address environmental cost recovery that
was excluded from the settlement. The procedural schedule established by the
presiding Administrative Law Judge provided for a hearing to commence in the
fall of 1998. However, at the request of Columbia Transmission and other active
parties, the schedule was suspended in May 1998, in order to afford the parties
an opportunity to pursue settlement discussions. As a result of these
discussions, the active parties reached an agreement in principle on the
overall components of an environmental settlement. The comprehensive agreement
in principle includes such major components as Columbia Transmission's total
allowed recovery of environmental remediation program costs and the disposition
of any proceeds received by Columbia Transmission from insurance carriers and
others. Columbia Transmission filed the stipulation and agreement with the FERC
on April 5, 1999. Initial comments were filed on April 26, 1999, and reply
comments filed on May 5, 1999. Based on these comments, the settlement is
supported or not opposed by all parties.
Sale of Facilities
During 1997, Columbia Transmission sold approximately 4,500 miles of its
gathering lines of which 2,700 miles were sold to Columbia Resources.
Approximately 750 miles of gathering facilities were sold to Columbia Resources
effective January 1999. There are approximately 800 miles of gathering lines
remaining to be sold.
In addition, Columbia Transmission has agreed to sell certain natural gas
pipeline facilities that consist of approximately 341 miles of pipeline,
together with property and associated facilities, located in New York and
Pennsylvania. The sale of these facilities was approved by the FERC in an order
issued in November 1998. By order issued on February 10, 1999, FERC denied
rehearing. On March 19, 1999, Lomak Petroleum, Inc. petitioned the D.C. Circuit
Court of Appeals to review and set aside FERC's orders. The parties are
proceeding to consummate this transaction. The sale of these assets would not
have a material impact on Columbia's consolidated financial results.
Discussions with FERC
The transmission and storage subsidiaries are in confidential and informal
discussions with the staff of the FERC (Staff) concerning the scope of
authorization for certain past transactions under the relevant filed tariffs.
The transmission and storage subsidiaries initiated these discussions with the
FERC. Because these discussions are in a very preliminary stage, management is
unable to reasonably estimate the amount that will have to be paid pursuant to
reimbursement or other remedies. These subsidiaries are providing information on
this matter to the Staff pursuant to an informal non-public inquiry being
conducted by the Staff.
19
<PAGE> 20
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
TRANSMISSION AND STORAGE OPERATIONS (CONTINUED)
Bankruptcy Matters
On November 28, 1995, Columbia and its wholly-owned subsidiary, Columbia
Transmission emerged from Chapter 11 protection of the United States Bankruptcy
Code under the jurisdiction of the United States Bankruptcy Court for the
District of Delaware (Bankruptcy Court). Both Columbia and Columbia Transmission
had operated under Chapter 11 protection from July 31, 1991, until emergence.
In July 1998, the Bankruptcy Court, granting a motion by Columbia Transmission,
entered an Order allowing the claim of the New Bremen Corporation (New Bremen)
in accordance with the Claims Mediator's Report and Recommendations and the
decision of the U.S. 5th Circuit Court of Appeals. In August 1998, New Bremen
filed a notice of appeal of this order to the U.S. District Court for the
District of Delaware. This litigation was the last remaining producer claim in
Columbia Transmission's bankruptcy proceeding. During the first quarter of 1999,
Columbia Transmission reached a settlement with New Bremen. The improvement to
Columbia's first quarter 1999 consolidated net income was $20.6 million. The
settlement was approved by the Bankruptcy Court on April 12, 1999, and on April
26, 1999, Columbia Transmission distributed the producer holdback amounts in
accordance with its Plan of Reorganization and the New Bremen settlement.
Throughput
Columbia Transmission's throughput consists of transportation and storage
services for local distribution companies and other customers within its market
area, which covers fifteen northeastern, mid-Atlantic, midwestern and southern
states and the District of Columbia. Throughput for Columbia Gulf reflects
mainline transportation services from Rayne, Louisiana, to West Virginia and
short-haul transportation services primarily from the Gulf of Mexico to an
interconnection in South Louisiana.
Throughput for the transmission and storage segment totaled 453.3 Bcf for the
first quarter of 1999, an increase of 28.7 Bcf over the same period last year,
primarily reflecting colder weather in the current period. Also increasing
throughput was additional service from Columbia Transmission's market expansion
project, which expanded its pipeline and storage services to meet increased
customer demand.
Operating Revenues
Total operating revenues were $253.3 million for the first three months of 1999,
an increase of $8.4 million over the same period last year, due in large part to
additional revenues from transportation and storage services. Also improving
revenues in 1999's first quarter was the benefit of increased service from
Columbia Transmission's market expansion project. Both periods included the sale
of storage base gas that was part of Columbia Transmission's overall 1997 rate
settlement. In the first quarter of 1999, approximately 6.9 Bcf was sold for a
gain of $14.4 million and in the same period in 1998, approximately 4.7 Bcf of
storage base gas was sold for a gain of $13.4 million.
Operating Income
First quarter 1999 operating income of $144.2 million, increased $26.4 million
over the same period last year, primarily reflecting the settlement of the
producer contract issue, mentioned above. The effect of the $8.4 million
increase in revenues was more than offset by $11.4 million higher operation and
maintenance costs. Included in 1999's operation and maintenance costs was $6.9
million of expense for an amount due to the parent company from Columbia
Transmission's bankruptcy-related settlement. This amount was recorded as a
corresponding decrease to operation and maintenance costs by the parent company.
In addition, in the first quarter of 1998, a $4.3 million improvement was
recorded for the reduction in postretirement benefit costs.
20
<PAGE> 21
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
DISTRIBUTION OPERATIONS
<TABLE>
<CAPTION>
Three Months
Ended March 31,
---------------------
1999 1998
------- -------
(millions)
<S> <C> <C>
NET REVENUES
Sales revenues $ 911.1 $ 744.0
Less: Cost of gas sold 666.6 481.5
------- -------
Net Sales Revenues 244.5 262.5
------- -------
Transportation revenues 107.0 57.7
Less: Associated gas costs 9.9 5.6
------- -------
Net Transportation Revenues 97.1 52.1
------- -------
Net Revenues 341.6 314.6
------- -------
OPERATING EXPENSES
Operation and maintenance 112.4 91.9
Depreciation 36.0 33.8
Other taxes 63.0 68.8
------- -------
Total Operating Expenses 211.4 194.5
------- -------
OPERATING INCOME $ 130.2 $ 120.1
======= =======
THROUGHPUT (Bcf)
Sales
Residential 69.1 72.0
Commercial 22.9 26.6
Industrial and other 1.0 1.6
------- -------
Total Sales 93.0 100.2
Transportation 107.9 84.1
------- -------
Total Throughput 200.9 184.3
Off-System Sales 156.3 29.0
------- -------
Total Sold or Transported 357.2 213.3
======= =======
SOURCES OF GAS FOR THROUGHPUT (Bcf)
Sources of Gas Sold
Spot market* 52.6 61.4
Producers 2.4 2.9
Storage withdrawals 61.9 63.7
Company use and other 132.4 1.2
------- -------
Total Sources of Gas Sold 249.3 129.2
Gas received for delivery to customers 107.9 84.1
------- -------
Total Sources 357.2 213.3
======= =======
</TABLE>
* Purchase contracts of less than one year.
21
<PAGE> 22
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
DISTRIBUTION OPERATIONS (CONTINUED)
Market Conditions
During the first quarter of 1999, weather in the market area served by
Columbia's distribution subsidiaries (Distribution) was 6% warmer than normal,
but 20% colder than in the first quarter of 1998, which was the warmest first
quarter on record. As a result, Distribution's weather-sensitive deliveries
increased 22.3 Bcf over the first three months of 1998.
Regulatory Matters
In Virginia, legislation has been signed by the governor that permits Columbia
Gas of Virginia, Inc. (Columbia of Virginia), upon approval by the Virginia
State Corporation Commission (VSCC), to offer all of its 178,000 customers the
opportunity to choose their natural gas supplier. This new legislation allows a
natural gas distribution company to file for unbundling its rates with the VSCC.
The plan cannot go into effect until July 1, 2000. In the interim, a special
legislative subcommittee will study the tax implications of natural gas
deregulation and make recommendations for tax changes. Columbia of Virginia has
been providing a pilot transportation program in the Gainesville market area of
Northern Virginia since late 1997 and plans to file in 1999 for permission to
expand the Customer CHOICE(SM) program statewide. Also, in April 1999, Columbia
of Virginia amended its 1998 rate application to revise its firm rates for
residential and small general service customers to recover most non-gas costs as
fixed monthly charges rather than volumetric charges.
Environmental Matters
Distribution's primary environmental issues relate to 16 former manufactured gas
plant sites. Investigations or remedial activities are currently underway at six
sites and remedial construction has been completed at two sites. Additional site
investigations may be required at some of the remaining sites. To the extent
Distribution's site investigations have been conducted, remediation plans
developed and any responsibility for remediation action established, the
appropriate estimated liabilities have been recorded. Regulatory assets have
also been recorded for a majority of these costs as rate recovery has been
authorized or is anticipated.
Voluntary Severance Plans
In January 1999, Columbia Gas of Pennsylvania, Inc. (Columbia of Pennsylvania)
announced a Voluntary Severance Program (VSP) available to all of its nearly 700
employees in its operations department. The program was an effort to bring
staffing levels into balance with anticipated work assignments. Stagnant market
growth, new technologies, a more modern pipeline system and a more efficient
management system for assigning work is permitting Columbia of Pennsylvania to
meet its operations obligations with fewer employees. In total, 37 professional,
manual and administrative/technical employees in the operations department have
elected to participate in the program. By combining the VSP with other workforce
reduction measures, Columbia of Pennsylvania has reduced staffing by about 45
full-time employees. These initiatives resulted in a first quarter 1999 charge
to operating expense of $1.5 million representing severance and benefits costs
for the participating employees, most of whom left the company by March 17,
1999.
Volumes
Total volumes sold and transported of 357.2 Bcf during the first quarter of 1999
increased 143.9 Bcf over the same period last year. In addition to the
throughput improvement attributable to this year's colder weather compared to
last year, off-system sales were up 127.3 Bcf as Distribution took advantage of
higher spot prices after March 1, 1999 to sell gas supplies available due to
this winter's warmer than normal weather.
22
<PAGE> 23
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
DISTRIBUTION OPERATIONS (CONTINUED)
Net Revenues
Net revenues for the three months ended March 31, 1999 were $341.6 million, up
$27 million from the first quarter of 1998, primarily due to this year's colder
weather.
Operating Income
Operating income for the first quarter of 1999 of $130.2 million increased $10.1
million over the same period in 1998. The period-to-period change from the
favorable impact on 1999 net revenues of the colder weather was partially offset
by a $15 million reduction in postretirement benefit costs in 1998 resulting
from the purchase of insurance for a portion of these liabilities.
23
<PAGE> 24
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
EXPLORATION AND PRODUCTION OPERATIONS
<TABLE>
<CAPTION>
Three Months
Ended March 31,
------------------------
1999 1998
-------- --------
(millions)
<S> <C> <C>
OPERATING REVENUES
Gas revenues $ 25.9 $ 33.6
Other revenues 4.6 3.8
-------- --------
Total Operating Revenues 30.5 37.4
-------- --------
OPERATING EXPENSES
Operation and maintenance 12.9 10.4
Depreciation and depletion 9.5 10.2
Other taxes 2.5 2.4
-------- --------
Total Operating Expenses 24.9 23.0
-------- --------
OPERATING INCOME $ 5.6 $ 14.4
======== ========
GAS PRODUCTION STATISTICS
Production (Bcf)
U.S 10.6 9.9
Canada -- --
-------- --------
Total 10.6 9.9
======== ========
Average Price ($ per Mcf)
U.S 2.44 3.38
Canada 2.64 --
OIL AND LIQUIDS PRODUCTION STATISTICS
Production (000 Bbls)
U.S 36 58
Canada 3 --
-------- --------
Total 39 58
======== ========
Average Price ($ per Bbl)
U.S 9.79 14.31
Canada 12.49 --
</TABLE>
24
<PAGE> 25
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
EXPLORATION AND PRODUCTION (CONTINUED)
Acquisition
On April 14, 1999, Columbia Resources signed an agreement with The Wiser Oil
Company to acquire its Appalachian Basin production and gathering assets. The
transaction is valued at approximately $28 million and was closed on May 12,
1999. Columbia Resources purchased a working interest in 487 natural gas and oil
wells, more than 100,000 net acres of developed and undeveloped property and a
natural gas gathering system. The assets are located primarily in southeastern
Kentucky and central West Virginia. Current production from the acquired assets
on a net revenue basis is approximately 8 million cubic feet of natural gas per
day. The transaction will include 42.7 billion cubic feet equivalent (Bcfe) of
proved reserves, which will increase Columbia Resources' reserve base to
approximately 844 Bcfe.
Volumes
Gas production for the first quarter of 1999 of 10.6 Bcf was up 0.7 Bcf over the
same period in 1998 reflecting new production brought online from wells drilled
and completed in late 1998. Columbia Resources anticipates its 1999 gas
production to total in excess of 50 Bcf as new wells continue to come online.
Operating Revenues
Operating revenues for the first three months of 1999 of $30.5 million,
decreased $6.9 million from the first quarter of 1998. Sharply lower gas prices
more than offset the increase in gas production. For the first quarter of 1999,
gas prices averaged $2.44 per Mcf, down $0.94 per Mcf, or 28%, from the first
quarter of 1998. Third party gathering revenues were essentially unchanged from
1998. As previously reported, certain gathering facilities were transferred from
Columbia Transmission to Columbia Resources. Revenues generated from operating
these facilities are largely offset by related operation and maintenance
expense.
To manage the uncertainty of natural gas prices, Columbia Resources has hedged
substantially all of its gas production from April through October 1999 that was
subject to price volatility, using various financial instruments. These
instruments include "no cost collars" with a floor of approximately $2.39 per
Mcf and an average ceiling of about $2.56 per Mcf. These collars, when combined
with the previously hedged positions give a price range for Columbia Resources'
1999 second and third quarter production of between $2.56 per Mcf to $2.65 per
Mcf.
Operating Income
Operating income of $5.6 million for the three months ended March 31, 1999,
decreased $8.8 million from the same period in 1998. This decline reflects the
$6.9 million decrease in operating revenues coupled with $2.5 million higher
operation and maintenance expense. These higher costs are primarily the result
of Columbia Resources' expanded asset base that includes additional gathering
facilities.
25
<PAGE> 26
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
MARKETING OPERATIONS
<TABLE>
<CAPTION>
Three Months
Ended March 31,
---------------------------
1999 1998
-------- --------
(millions)
<S> <C> <C>
OPERATING REVENUES
Gas revenues $1,134.9 $ 859.1
Power revenues 194.7 6.3
-------- --------
Total Operating Revenues 1,329.6 865.4
Less: Products purchased 1,324.0 854.1
-------- --------
Gross Margin 5.6 11.3
-------- --------
OPERATING EXPENSES
Operation and maintenance 23.9 15.5
Depreciation 2.0 0.7
Other taxes 1.2 0.6
-------- --------
Total Operating Expenses 27.1 16.8
-------- --------
OPERATING (LOSS) $ (21.5) $ (5.5)
======== ========
MARKETING SALES
Gas (Bcf) 553.8 364.2
Power (Gwh) 7,846 305
</TABLE>
26
<PAGE> 27
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
MARKETING OPERATIONS (CONTINUED)
Columbia's marketing operations have significantly expanded over the past year.
Columbia Energy Services is an industry leader in number of retail customers and
now serves nearly half a million customers in 10 states, twice the level of
retail customers of a year ago. Gas sales for the first quarter of 1999 have
increased 52% over the same period last year while power sales increased to
7,846 gigawatt hours in the first quarter of 1999 compared to 305 gigawatt hours
in the first quarter last year. This growth has strained Columbia Energy
Services' infrastructure and necessitated investments to improve the
infrastructure and to capture market share as retail customers are allowed to
choose their energy commodity supplier.
While continuing to work to improve its infrastructure, over the near term,
Columbia Energy Services is focusing its efforts in areas where Columbia has an
established presence, primarily in the east, mid-continent, and Gulf coast
regions. The strategy going forward is to market a broader array of products to
this established customer base with a goal to increase margins and shareholder
value.
Gross Margin
For the first three months of 1999, the gross margin was $5.6 million, a
decrease of $5.7 million compared to the same period last year. The decrease in
the gross margin was due primarily to the effect that warm weather had on retail
gas operations. The substantial increase in power sales volumes tempered the
decrease in the gross margin. The higher gas sales volumes resulted primarily
from increased deliveries to low margin wholesale customers.
Operating Loss
The marketing operations reported an operating loss of $21.5 million in the
first quarter of 1999, compared to a $5.5 million operating loss in the same
period last year. The additional loss primarily reflected the $5.7 million
decrease in gross margins and a $10.3 million increase in operating expenses.
Operation and maintenance expense was up $8.4 million due to increased
investment in infrastructure, costs associated with customer additions and a
larger workforce. The workforce, which now totals approximately 440 employees,
grew by about 140 over the first quarter of 1998. Depreciation expense increased
$1.3 million in 1999's first quarter reflecting depreciation of software systems
implemented in mid-1998.
27
<PAGE> 28
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
PROPANE, POWER GENERATION AND LNG OPERATIONS
<TABLE>
<CAPTION>
Three Months
Ended March 31,
-----------------------
1999 1998
------- -------
(millions)
<S> <C> <C>
NET REVENUES
Propane revenues $ 33.3 $ 24.7
Less: Products purchased 16.1 12.9
------- -------
Net Propane Revenues 17.2 11.8
Power generation 2.0 1.5
Other revenues 5.0 4.0
------- -------
Net Revenues 24.2 17.3
------- -------
OPERATING EXPENSES
Operation and maintenance 13.0 8.3
Depreciation 1.4 1.0
Other taxes 0.7 0.5
------- -------
Total Operating Expenses 15.1 9.8
------- -------
OPERATING INCOME $ 9.1 $ 7.5
======= =======
PROPANE SALES (MILLIONS OF GALLONS)
Retail 30.0 22.8
Wholesale and Other 9.0 2.0
------- -------
Total Propane Sales 39.0 24.8
======= =======
</TABLE>
28
<PAGE> 29
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
PROPANE, POWER GENERATION AND LNG OPERATIONS (CONTINUED)
Acquisitions
National Propane Partners, L.P.
In April 1999, Columbia Propane announced that it was making a cash tender
offer, through its subsidiaries, to acquire all of the outstanding common units
of National Propane Partners, LP (National Propane). National Propane agreed to
merge into a subsidiary partnership of Columbia Propane. The approximately $210
million transaction involves cash payments to the unit holders, refinancing of
about $141 million in debt, and payment of about $2.1 million to the general
partners of National Propane. The valuation of the transaction reflects the
prepayment by the parent of the general partners of National Propane of
approximately $14.9 million of debt.
On May 7, 1999, Columbia Propane announced that, through its subsidiaries, it
had accepted for payment approximately 5.9 million common units, or
approximately 88.4% of the outstanding common units, of National Propane at $12
per common unit. The completion of the merger is subject to certain closing
conditions with any remaining outstanding common units of National Propane then
being converted into the right to receive $12 per common unit, without interest.
When completed, the acquisition of National Propane will add more than 210,000
retail and wholesale customers in 24 states, extending Columbia Propane's
presence from the mid-Atlantic and northeast to the southeast, midwest and
western regions of the United States.
Carlos R. Leffler, Inc.
Also in April 1999, Columbia Propane, through its subsidiary, Columbia Petroleum
Corporation (Columbia Petroleum), signed a definitive agreement to acquire
certain propane and petroleum product assets and associated properties from
Carlos R. Leffler, Inc. (Leffler) and other Leffler entities. The transaction
closed effective May 11, 1999, and is valued at approximately $60 million,
exclusive of inventory and subject to certain post-closing adjustments.
Columbia Propane received the propane assets, consisting of bulk storage
facilities with a capacity of over 1.5 million gallons, a pipeline terminal with
over 1.2 million gallons of storage, a propane distribution fleet and wholesale
and retail operations serving central and eastern Pennsylvania. In 1998, the
Leffler propane business served approximately 12,500 customers.
Columbia Petroleum now owns and operates the petroleum assets, including five
pipeline terminals, bulk storage facilities with a capacity of over 45 million
gallons, and a wholesale and retail petroleum products distribution network
serving the eastern half of Pennsylvania, southeastern New York, Maryland and
Delaware. In 1998, the Leffler petroleum business had approximately 36,000
customers and sales of approximately 373 million gallons. Products sold by the
petroleum business include fuel oil, various grades of diesel fuel and gasoline,
kerosene and industrial and automotive lubricants.
The National Propane acquisition, assuming successful consummation, and Leffler
acquisition would nearly triple the number of propane customers served and
expand Columbia Propane's market area from eight to 35 states, making it one of
the largest propane distribution companies in the nation.
Columbia Network Services Corporation (Columbia Network Services)
In the first quarter of 1999, Columbia Network Services discontinued operations
of its wholly-owned subsidiary, Energy Net, L.L.C., which was involved in the
development of an electronic system that was to serve as a central access point
for the scheduling of natural gas transportation. The cost of
29
<PAGE> 30
PART I - FINANCIAL INFORMATION
ITEM 2 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
PROPANE, POWER GENERATION AND LNG OPERATIONS (CONTINUED)
discontinuing this operation was immaterial to Columbia's consolidated financial
statements.
Net Revenues
Net revenues for the first quarter of 1999 increased $6.9 million over the same
period last year to $24.2 million. Propane sales were up significantly in the
current quarter reflecting acquisitions made in 1998, however, sales were still
hampered by the warmer than normal weather. Columbia Electric Corporation's
power generation net revenues for the three months ended March 31, 1999,
increased $500,000 over the same period last year due to higher project
revenues.
Operating Income
Operating income for the first three months of 1999 was $9.1 million, up $1.6
million over the first quarter of 1998. The $6.9 million increase in net
revenues was partially offset by $5.3 million higher operating expenses. The
higher expense was primarily due to a $4.7 million increase in operation and
maintenance expense that was attributable to the acquisition of three propane
companies during 1998.
30
<PAGE> 31
Item 3. Quantitative and Qualitative Disclosures About Market Risk
There have not been any material changes regarding quantitative
and qualitative disclosures about market risk from the information
reported in Columbia's 1998 Annual Report on Form 10-K other than
the information reported on page 16 of the Management's Discussion
and Analysis under "Market Risk Exposure."
PART II - OTHER INFORMATION
Item 1. Legal Proceedings
No new reportable matters have arisen and there have been no
material developments in any legal proceedings reported in
Columbia's Annual Report on Form 10-K for the year ended December
31, 1998 except as follows:
I. Purchase and Production Matters
A. New Bremen Corp. v. Columbia Gas Transmission Corp. and Columbia
Gulf Transmission Co., No. 88V-631 (Dist. Ct. Austin County, TX);
In re The Columbia Gas System, Inc. and Columbia Gas Transmission
Corporation, No. 91-893 and No. 91-804 (U.S. bankr. Ct. Dist. Of
Del.). The Bankruptcy Court approved the settlement on April 12,
1998. Payment was made on April 26, 1999. This matter is now
concluded.
II. Other
A. Cathodic Protection. The history related to this matter is
discussed in Columbia's 1998 Annual Report on Form 10-K. On April
29, 1999, the staff of the Virginia State Corporation Commission
(VSCC) issued a Notice of Probable Violation, indicating it had
discovered numerous "probable violations" of the VSCC's pipeline
safety regulations. Columbia of Virginia is currently reviewing
and preparing its response to the staff's Notice.
Item 2. Changes in Securities and Use of Proceeds
None
Item 3. Defaults Upon Senior Securities
None
Item 4. Submission of Matters to a Vote of Security Holders
None
Item 5. Other Information
None
31
<PAGE> 32
Item 6. Exhibits and Reports on Form 8-K
Exhibit
Number
12 Statements of Ratio of Earnings to Fixed Charges
27 Financial Data Schedule
The following reports on Form 8-K were filed during the first
quarter of 1999.
<TABLE>
<CAPTION>
Financial
Item Statements
Reported Included Date of Event Date Filed
-------- ----------- ------------- ----------
<S> <C> <C> <C> <C>
5 Yes* February 11, 1999 February 11, 1999
</TABLE>
* Summary of Financial and Operational data for three and twelve
months ended December 31, 1998.
32
<PAGE> 33
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
Columbia Energy Group
(Registrant)
Date: May 13, 1999 By: /s/ Jeffrey W. Grossman
-----------------------------------------
Jeffrey W. Grossman
Vice President and Controller
(Principal Accounting Officer
and Duly Authorized Officer)
33
<PAGE> 1
Statements of Ratio of Earnings to Fixed Charges
($ in millions)
<TABLE>
<CAPTION>
Twelve Months Twelve Months
Ended March 31, Ended December 31,
------------------ ---------------------------------------------------
1999 1998 1998 1997 1996 1995 1994
------- ------- ------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C> <C> <C>
Consolidated Income (Loss) from Continuing Operations
before Income Taxes 421.8 376.6 401.0 392.2 337.5 (643.0) 392.2
Adjustments:
Interest during construction (2.5) (2.6) (2.1) (3.0) (1.1) (20.2) --
Distributed (Undistributed) equity income (2.4) 3.8 (0.4) 3.6 1.5 (7.9) (0.9)
Fixed charges * 172.2 183.1 173.1 182.0 184.6 1,061.3 33.7
------- ------- ------- ------- ------- ------- -------
Earnings Available 589.1 560.9 571.6 574.8 522.5 390.2 425.0
------- ------- ------- ------- ------- ------- -------
Fixed Charges:
Interest on long-term and short-term debt 143.7 146.4 145.4 145.6 150.8 987.2 0.7
Other interest 11.2 15.8 9.6 15.4 13.5 53.6 14.1
Portion of rentals representing interest 17.3 20.9 18.1 21.0 20.3 20.5 18.9
------- ------- ------- ------- ------- ------- -------
Total Fixed Charges **, *** 172.2 183.1 173.1 182.0 184.6 1,061.3 33.7
------- ------- ------- ------- ------- ------- -------
Ratio of Earnings to Fixed Charges 3.42 3.06 3.30 3.16 2.83 N/A (a) 12.61
======= ======= ======= ======= ======= ======= =======
</TABLE>
(a) To achieve a one-to-one coverage, the Corporation would need an additional
$671.1 million of earnings for the twelve months ended December 31, 1995.
* Amounts for the twelve months December 31, 1994 through December 31, 1996
have been restated to conform to 1999 presentation.
** This amount excludes approximately $230 million of interest expense not
recorded for the twelve months ended December 31, 1994. This amount includes
interest expense of $982.9 million including the write-off of unamortized
discounts on debentures recorded in 1995.
*** This amount excludes $8.6 million of interest expense not recorded with
respect to the registrant's guarantee of LESOP Trust's debentures for the twelve
months ended December 31, 1994.
34
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<CIK> 0000022099
<NAME> CEG
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<S> <C>
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<PERIOD-START> JAN-01-1999
<PERIOD-END> MAR-31-1999
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 4,088,500
<OTHER-PROPERTY-AND-INVEST> 621,600
<TOTAL-CURRENT-ASSETS> 2,018,100
<TOTAL-DEFERRED-CHARGES> 122,900
<OTHER-ASSETS> 381,200
<TOTAL-ASSETS> 7,232,300
<COMMON> 835,100
<CAPITAL-SURPLUS-PAID-IN> 763,700
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<TOTAL-COMMON-STOCKHOLDERS-EQ> 2,099,300
0
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