<PAGE> 1
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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(MARK ONE)
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 1998
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM ______________TO _____________
COMMISSION FILE NUMBER 1-3187
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED
(Exact name of registrant as specified in its charter)*
<TABLE>
<S> <C>
TEXAS 74-0694415
(State or other jurisdiction of incorporation or (I.R.S. employer identification number)
organization)
1111 LOUISIANA
HOUSTON, TEXAS 77002 (713) 207-3000
(Address and zip code of principal executive offices) (Registrant's telephone number, including area code)
</TABLE>
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF
THE ACT:
<TABLE>
<CAPTION>
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED
<S> <C>
Common Stock, without par value, New York Stock Exchange
and associated rights to purchase preference stock Chicago Stock Exchange
7% Automatic Common Exchange New York Stock Exchange
Securities due July 1, 2000
HL&P Capital Trust I 8.125% Trust New York Stock Exchange
Preferred Securities, Series A
REI Trust I 7.20% Trust Originated Preferred Securities, New York Stock Exchange
Series C**
</TABLE>
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
Preferred Stock, cumulative, no par, $4 series
COMMISSION FILE NUMBER 1-13265
RELIANT ENERGY RESOURCES CORP.
(FORMERLY NORAM ENERGY CORP.)
(Exact name of registrant as specified in its charter)
<TABLE>
<S> <C>
DELAWARE 76-0511406
(State or other jurisdiction of incorporation or organization) (I.R.S. employer identification number)
1111 LOUISIANA
Houston, Texas 77002 (713) 207-3000
(Address and zip code of principal executive offices) (Registrant's telephone number, including area code)
</TABLE>
<PAGE> 2
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
<TABLE>
<CAPTION>
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED
<S> <C>
NorAm Financing I 6 % Convertible Trust New York Stock Exchange
Originated Preferred Securities
6% Convertible Subordinated Debentures due 2012 New York Stock Exchange
</TABLE>
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: NONE
RELIANT ENERGY RESOURCES CORP. MEETS THE CONDITIONS SET FORTH IN GENERAL
INSTRUCTION I(1)(a) AND (b) OF FORM 10-K AND IS THEREFORE FILING THIS FORM 10-K
WITH THE REDUCED DISCLOSURE FORMAT.
Indicate by check mark whether each of the registrants: (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 if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of each of the registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K. [X]
The aggregate market value of the voting stock held by non-affiliates of
Houston Industries Incorporated d/b/a Reliant Energy, Incorporated (Company) was
$8,242,087,474 as of March 11, 1999, using the definition of beneficial
ownership contained in Rule 13d-3 promulgated pursuant to the Securities
Exchange Act of 1934 and excluding shares held by directors and executive
officers. As of March 11, 1999, the Company had 296,329,510 shares of Common
Stock outstanding, including 11,424,063 ESOP shares not deemed outstanding for
financial statement purposes. Excluded from the number of shares of Common Stock
outstanding are 91,512 shares held by the Company as treasury stock. As of March
11, 1999, all 1,000 outstanding shares of Reliant Energy Resources Corp.'s
Common Stock were held by the Company.
Portions of the definitive proxy statement relating to the 1999 Annual
Meeting of Shareholders of the Company, which will be filed within 120 days of
December 31, 1998, are incorporated by reference in Item 10, Item 11, Item 12
and Item 13 of Part III of this Form 10-K.
*On May 5, 1999, the Company's shareholders will vote on a proposal to
amend the Articles of Incorporation of the Company to change its name from
"Houston Industries Incorporated" to "Reliant Energy, Incorporated."
**Issued on February 26, 1999.
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<PAGE> 3
THIS COMBINED ANNUAL REPORT ON FORM 10-K IS SEPARATELY FILED BY HOUSTON
INDUSTRIES INCORPORATED, d/b/a RELIANT ENERGY, INCORPORATED AND RELIANT ENERGY
RESOURCES CORP. (FORMERLY KNOWN AS NORAM ENERGY CORP.). INFORMATION CONTAINED
HEREIN RELATING TO RELIANT ENERGY RESOURCES CORP. IS FILED BY RELIANT ENERGY,
INCORPORATED AND SEPARATELY BY RELIANT ENERGY RESOURCES CORP. ON ITS OWN BEHALF.
RELIANT ENERGY RESOURCES CORP. MAKES NO REPRESENTATION AS TO INFORMATION
RELATING TO RELIANT ENERGY, INCORPORATED (EXCEPT AS IT MAY RELATE TO RELIANT
ENERGY RESOURCES CORP. AND ITS SUBSIDIARIES), RELIANT ENERGY INTERNATIONAL, INC.
(FORMERLY KNOWN AS HOUSTON INDUSTRIES ENERGY, INC.), RELIANT ENERGY POWER
GENERATION, INC. (FORMERLY KNOWN AS HI POWER GENERATION, INC.) OR ANY OTHER
AFFILIATE OR SUBSIDIARY OF RELIANT ENERGY, INCORPORATED.
TABLE OF CONTENTS
<TABLE>
<S> <C> <C>
PART I
Item 1. Business.......................................................................................1
Item 2. Properties....................................................................................21
Item 3. Legal Proceedings.............................................................................23
Item 4. Submission of Matters to a Vote of Security Holders...........................................23
PART II
Item 5. Market for the Company's Common Equity and Related Stockholder Matters........................24
Item 6. Selected Financial Data of the Company........................................................25
Company
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations of the Company..........................................................27
Item 7A Quantitative and Qualitative Disclosures About Market Risk....................................54
Item 8. Financial Statements and Supplementary Data of the Company....................................58
Resources
Item 7. Management's Narrative Analysis of the Results of Operations of Reliant Energy Resources Corp.
and Consolidated Subsidiaries................................................................109
Item 8. Financial Statements and Supplementary Data of Resources.....................................113
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.........148
PART III
Item 10. Directors and Executive Officers of the Company and Resources................................148
Item 11. Executive Compensation.......................................................................148
Item 12. Security Ownership of Certain Beneficial Owners and Management...............................148
Item 13. Certain Relationships and Related Transactions...............................................148
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K..............................149
</TABLE>
i
<PAGE> 4
CAUTIONARY STATEMENT REGARDING
FORWARD LOOKING INFORMATION
From time to time, Reliant Energy, Incorporated (Company) and Reliant
Energy Resources Corp. (Resources) may make statements regarding their
assumptions, projections, expectations, intentions or beliefs about future
events. These statements and other statements that are not historical facts are
intended as "forward-looking statements" under the Private Securities Litigation
Reform Act of 1995. The Company and Resources caution that assumptions,
projections, expectations, intentions or beliefs about future events may and
often do vary materially from actual results and the differences between
assumptions, projections, expectations, intentions or beliefs and actual results
can be material. Accordingly, there can be no assurance actual results will not
differ materially from those expressed or implied by the forward-looking
statements.
The following are some of the factors that could cause actual results to
differ from those expressed or implied in forward-looking statements: (i) state
and federal legislative and regulatory initiatives that affect cost and
investment recovery, have an impact on rate structures and affect the speed and
degree to which competition enters the electric and natural gas industries; (ii)
industrial, commercial and residential growth in service territories of the
Company and Resources; (iii) the weather and other natural phenomena; (iv) the
timing and extent of changes in commodity prices and interest rates; (v) changes
in environmental and other laws and regulations to which the Company, Resources
and their respective subsidiaries are subject or other external factors over
which the Company and Resources have no control; (vi) the results of financing
efforts; (vii) growth in opportunities for the Company's and Resources'
subsidiaries and diversified operations; and (viii) risks incidental to the
Company's overseas operations (including the effects of fluctuations in foreign
currency exchange rates).
The following sections of this Form 10-K contain forward-looking statements:
"Business -- Certain Factors," "Business -- Electric Operations -- System
Capability," "Business -- Electric Operations -- Capital Expenditures,"
"Business -- Electric Operations -- Fuel," "Business -- Wholesale Energy --
Power Generation," "Business -- Wholesale Energy-- Energy Marketing and Risk
Management," "Business -- International -- Major Foreign Investments," "Business
- -- Regulation -- Federal Energy Regulatory Commission," and "Business --
Environmental Matters" in Item 1 of this Form 10-K; "Legal Proceedings" in Item
3 of this Form 10-K; "Management's Discussion and Analysis of Financial
Condition and Results of Operations of the Company -- Results of Operations by
Business Segment -- Wholesale Energy ," "Management's Discussion and Analysis of
Financial Condition and Results of Operations of the Company -- Results of
Operations by Business Segment -- International," "Management's Discussion and
Analysis of Financial Condition and Results of Operations of the Company --
Certain Factors Affecting Future Earnings of the Company and its Subsidiaries,"
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Certain Factors Affecting Future Earnings of the
Company and its Subsidiaries -- Competition -- Other Operations," "Management's
Discussion and Analysis of Financial Condition and Results of Operations of the
Company -- Certain Factors Affecting Future Earnings of the Company and its
Subsidiaries -- Impact of the Year 2000 Issue and Other System Implementation
Issues," "Management's Discussion and Analysis of Financial Condition and
Results of Operations of the Company -- Certain Factors Affecting Future
Earnings of the Company and its Subsidiaries -- Risks of International
Operations," "Management's Discussion and Analysis of Financial Condition and
Results of Operations of the Company -- Certain Factors Affecting Future
Earnings of the Company and its Subsidiaries -- Environmental Expenditures" and
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Liquidity and Capital Resources -- Company
Consolidated Capital Requirements" and "-- Consolidated Sources of Capital
Resources and Liquidity" in Item 7 of this Form 10-K; and "Quantitative and
Qualitative Disclosures About Market Risk" in Item 7A of this Form 10-K.
ii
<PAGE> 5
PART I
ITEM 1. BUSINESS.
Reliant Energy, Incorporated (Company) is a diversified international
energy services company. Its Reliant Energy HL&P division (formerly Houston
Lighting & Power Company) provides electric utility services to approximately
1.6 million customers in Houston, Texas and surrounding areas on the Texas Gulf
Coast. Its largest subsidiary, Reliant Energy Resources Corp. (Resources)
(formerly NorAm Energy Corp.), is a natural gas utility serving over 2.8 million
customers in Arkansas, Louisiana, Minnesota, Mississippi, Oklahoma and Texas.
Resources, through its subsidiaries, is also a major interstate natural gas
pipeline company and a provider of energy marketing services.
The Company's other principal subsidiaries include Reliant Energy
International, Inc. (formerly Houston Industries Energy, Inc.) which
participates in the privatization of foreign generating and distribution
facilities and the development and acquisition of foreign independent power
projects, and Reliant Energy Power Generation, Inc. (formerly Houston Industries
Power Generation, Inc.), which participates in the acquisition, development and
operation of non-rate regulated power generation assets.
The Company, subject to certain limited exceptions, is exempt from
regulation as a public utility holding company pursuant to Section 3(a)(2) of
the Public Utility Holding Company Act of 1935, as amended (1935 Act). For
additional information regarding the Company's status under the 1935 Act, see
"--Regulation--Public Utility Holding Company Act."
The Company, incorporated in 1906, is a Texas corporation. Resources,
incorporated in 1996, is a Delaware corporation. The executive offices of the
Company and Resources are located at 1111 Louisiana, Houston, Texas 77002, P.O.
Box 4567 (telephone number 713-207-3000). On May 5, 1999, the Company's
shareholders will vote on a proposal to amend the Company's Restated Articles of
Incorporation to change its name from "Houston Industries Incorporated" to
"Reliant Energy, Incorporated."
CERTAIN FACTORS
The Company's and its subsidiaries' operations are affected by various
factors, including competition, legislative and regulatory changes, stringent
environmental regulations, contingencies associated with nuclear plant
ownership, diversification into businesses outside of traditional regulated
utility operations and currency fluctuations and emerging market risks in
connection with international operations. The effects of these and other factors
on the business and operations of the Company and its subsidiaries are described
in "Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Certain Factors Affecting Future Earnings of the
Company and its Subsidiaries."
Regulation of electric utility operations on both state and federal levels
is in flux, with the goal of, among other things, enhancing competition. The
Texas legislature is considering several bills relating to the deregulation of
retail electricity sales. The adoption of such legislation is expected to have a
major impact on the Company. For information regarding these developments, as
they affect the Company, including without limitation, the Company's ability to
recover its existing investment in certain electric utility facilities, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Certain Factors Affecting Future Earnings of the
Company and its Subsidiaries -- Competition and Restructuring of Electric
Utility Industry," which section is incorporated herein by reference.
BUSINESS SEGMENTS
Effective January 1, 1998, the Company reconfigured its consolidated
financial reporting segments to include the following: Electric Operations,
Natural Gas Distribution, Interstate Pipelines, Wholesale Energy Marketing and
Generation (Wholesale Energy), International and Corporate. Electric Operations
includes the operations of Reliant
1
<PAGE> 6
Energy HL&P. Natural Gas Distribution includes the gas utility operations of
Resources. Interstate Pipeline includes the interstate natural gas pipeline
operations of Reliant Energy Gas Transmission Company (REGT) and Mississippi
River Transmission Corporation (MRT). Wholesale Energy includes the operations
of Reliant Energy Power Generation, Inc. (Power Generation), as well as the
energy marketing and trading operations of Reliant Energy Services, Inc.
(Reliant Energy Services) and the natural gas gathering operations of Reliant
Energy Field Services. International includes the operations of Reliant Energy
International, Inc. (Reliant Energy International). Corporate includes the
operations of Reliant Energy Retail, Inc. (Reliant Energy Retail), which
conducts a non-rate regulated retail services business, certain real estate
holdings of the Company and corporate expenses.
For financial and accounting information regarding the Company's segments,
see "Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Results of Operations by Business Segment" and Note
15 to the Company's Consolidated Financial Statements, which note is
incorporated herein by reference.
Information regarding historical and projected capital expenditures for
each segment is set forth in "Management's Discussion and Analysis of Financial
Condition and Results of Operations of the Company -- Liquidity and Capital
Resources -- Company's Consolidated Capital Requirements." Information regarding
the impact of competition on each segment is set forth in "Management's
Discussion and Analysis of Financial Condition and Results of Operations on the
Company -- Certain Factors Affecting Future Earnings of the Company and its
Subsidiaries -- Competition and Restructuring of the Electric Utility Industry"
and "-- Competition -- Other Operations," which sections are incorporated
herein by reference. Information regarding regulatory matters affecting each
segment is set forth below under "-- Regulation" and Note 3 to the Company's
Consolidated Financial Statements.
The following sections describe generally the business of each of the
Company's segments.
ELECTRIC OPERATIONS
The Electric Operations segment includes Reliant Energy HL&P, the Company's
regulated electric utility division, which generates, purchases, transmits and
distributes electricity to approximately 1.6 million residential, commercial and
industrial customers in a 5,000 square-mile service area on the Texas Gulf
Coast, including Houston, Texas, the nation's fourth largest city. The Company's
non-rate regulated generation business is conducted by Power Generation. For
information regarding Power Generation, see "-- Wholesale Energy." For the year
ended December 31, 1998, Electric Operations represented approximately 38% of
the Company's total consolidated revenues and 69% of its operating income. For
the years ended December 31, 1997 and 1996, Electric Operations represented
approximately 62% and 98%, respectively, of the Company's total consolidated
revenues and 93% and 100%, respectively, of its operating income.
All projections and other forward-looking data set forth under "Electric
Operations," including information regarding System Capability and Capital
Expenditures, assume the continued existence of a cost-based regulatory system.
SERVICE AREA
Houston's economy, although it has become increasingly diversified over the
past ten years, is still centered primarily on energy sector industries, such as
oil companies, petrochemical and refining complexes, industrial and
petrochemical construction firms and natural gas distribution and processing
centers. During the year ended December 31, 1998, energy sector industries
accounted for approximately 33% of Electric Operations' industrial electric base
revenues and 8% of its total electric base revenues. Other important sectors of
Houston's economy include the Port of Houston, the Johnson Space Center, the
Texas Medical Center and a growing electronics and computer industry.
The Company is a member of the Electric Reliability Council of Texas, Inc.
(ERCOT) and is interconnected to a transmission grid encompassing most of the
State of Texas.
2
<PAGE> 7
ELECTRIC UTILITY ASSETS
The Company owns and operates (i) 12 electric generating stations (62
generating units) with a combined turbine nameplate rating of 13,554,608
kilowatts (KW) and (ii) 213 major substation sites (240 substations) having a
total installed rated transformer capacity of 53,413 megavolt amperes (Mva). The
Company is one of four co-owners of the South Texas Project Electric Generating
Station (South Texas Project), a nuclear generating plant consisting of two
1,250 megawatt (MW) nuclear generating units in which the Company has a 30.8%
ownership interest. All of the electric generating stations and other operating
properties used in the business of Electric Operations are located in the State
of Texas. For additional information regarding the assets used in Electric
Operations' business, see "Properties" in Item 2 of this Form 10-K.
SYSTEM CAPABILITY
The following table sets forth information regarding Electric Operations'
system capability:
<TABLE>
<CAPTION>
INSTALLED FIRM
NET PURCHASED CALCULATED
CAPABILITY POWER TOTAL NET MAXIMUM HOURLY FIRM % CHANGE RESERVE
AT PEAK CONTRACTS CAPABILITY DEMAND FROM MARGIN
YEAR (MW) (MW)(1) (MW) DATE MW(2)(3) PRIOR YEAR (%)
- ---------------------- ------------- ------------- ------------- ------------- ------------- ------------ ----------
<S> <C> <C> <C> <C> <C> <C> <C>
1994............... 13,666 720 14,386 Jun. 28 11,126 (1.9) 29.3
1995............... 13,921 445 14,366 Jul. 27 11,452 2.9 25.4
1996............... 13,960 445 14,405 Jul. 23 11,694 2.1 23.2
1997............... 13,960 445 14,405 Aug. 21 12,246 4.7 17.6
1998............... 14,040 320 14,360 Aug. 3 13,006 6.2 10.4
</TABLE>
- ----------
(1) Purchased power capability for 1998 excludes a 125 MW contract that expired
in June 1998. For additional information on purchased power contracts, see
"-- Fuel -- Purchased Power Contracts."
(2) Excludes loads on interruptible service tariffs, residential direct load
control and commercial/industrial load cooperative capability. Including
these loads, the maximum hourly demand served in 1998 was 14,272 MW
compared to 13,459 MW in 1997.
(3) Maximum hourly firm demand increased in 1998 primarily due to significantly
warmer than normal summer weather.
Based on present trends, the Company estimates that the maximum hourly firm
demand for electricity in Electric Operations' service area will grow at a
compound annual rate of approximately 1.4% over the next ten years. Assuming
average weather conditions and including the net effects of demand-side
management programs, the Company projects that Electric Operations' reserve
margin in excess of maximum hourly firm demand load requirements will be 15% by
2001 (a reserve margin which the Company intends to maintain for long-term
planning purposes). The reduced reserve margins for 1998 reflect the extremely
hot weather conditions in Electric Operations' service area during that summer,
which increased system peak load by approximately 400 MW.
Electric Operations experiences significant seasonal variation in its sales
of electricity. Sales during the summer months are higher than sales during
other months of the year due to the reliance on air conditioning in Electric
Operations' service territory.
CAPITAL EXPENDITURES
The Company has an ongoing program to maintain the existing production,
transmission and distribution facilities of Electric Operations and to expand
its physical plant in response to customer needs. Assuming a target reserve
margin of 15%, the Company does not currently forecast a need for additional
capacity until 2002. However, no determination has been made by the Company as
to whether it would build or seek to purchase additional capacity in order to
meet additional requirements for capacity in 2002 or thereafter. Any additional
capacity requirements would be subject to public solicitation pursuant to the
integrated resource planning rules of the Public Utility Commission of Texas
(Texas Utility Commission).
3
<PAGE> 8
In 1998, Electric Operations' capital expenditures were approximately $429
million, excluding Allowance for Funds Used During Construction (AFUDC).
Electric Operations' capital program (excluding AFUDC) is currently estimated to
be approximately $490 million in 1999, $432 million in 2000 and $379 million in
2001. These expenditures relate primarily to improvements to Electric
Operations' existing electric generating, distribution and general plant
facilities. For the three-year period ending December 31, 2001, the aggregate
capital program for Electric Operations is estimated to be:
<TABLE>
<CAPTION>
PERCENT OF
AMOUNT TOTAL
(MILLIONS) EXPENDITURES
---------- ------------
<S> <C> <C>
Generating facilities.......................................................... $ 181 14%
Transmission facilities........................................................ 125 10
Distribution facilities........................................................ 483 37
Substation facilities.......................................................... 119 9
General plant facilities....................................................... 335 26
Nuclear fuel................................................................... 58 4
---------- ---------
Total................................................................ $ 1,301 100%
</TABLE>
Actual capital expenditures will vary from estimates as a result of
numerous factors, including, but not limited to, changes in the rate of
inflation, availability and relative cost of fuels and purchased power, changes
in environmental laws, regulatory and legislative changes and the effect of
regulatory proceedings. For information regarding expenditures associated with
nuclear fuel costs and environmental programs, see "-- Fuel -- Nuclear Fuel
Supply" and "Management's Discussion and Analysis of Financial Condition and
Results of Operations of the Company -- Certain Factors Affecting Future
Earnings of the Company -- Environmental Expenditures."
Actual capital expenditures could be significantly affected if Electric
Operations were forced to separate its generation and distribution activities
and sell its generating facilities as has occurred in some states in recent
years. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations of the Company -- Future Earnings of the Company and its
Subsidiaries -- Competition and Restructuring of the Electric Utility Industry
- -- Legislative Proposals."
FUEL
Electric Operations' historical and estimated future energy mix are set
forth below. Estimates are based on current assumptions regarding the cost and
availability of fuel, plant operation schedules, load growth, load management
and the impact of environmental regulations.
<TABLE>
<CAPTION>
ENERGY MIX (%)
----------------------------------
HISTORICAL ESTIMATED
---------- --------------------
1998 1999 2002
---------- ------- -------
<S> <C> <C> <C>
Natural Gas ......................................... 33 34 29
Coal and Lignite..................................... 38 43 44
Nuclear ............................................. 8 8 8
Purchased Power ..................................... 21 15 19
--- --- ---
Total ..................................... 100 100 100
=== === ===
</TABLE>
These estimates reflect the Company's existing sources of fuel supply. For
information regarding current and historical fuel costs, see "Management's
Discussion and Analysis of Financial Condition and Results of Operations of the
Company -- Results of Operations by Business Segment -- Electric Operations --
Fuel and Purchased Power Expense--Electric Operations" in Item 7 of this Report,
which information is incorporated herein by reference.
4
<PAGE> 9
Natural Gas Supply. During 1998, Electric Operations purchased
approximately 41% of its natural gas requirements pursuant to long-term
contracts with two suppliers, KN Energy, Inc. and Enron Corp, which contracts
expire in 2004 and 2002, respectively. Electric Operations purchased an
additional 20% of its natural gas requirements under long-term contracts with
other suppliers, and the remaining 39% of its natural gas requirements on the
spot market. Substantially all of Electric Operations' natural gas contracts
contain pricing provisions based on fluctuating spot market prices.
Based on the current market for and availability of natural gas, the
Company believes that Electric Operations will be able to replace the supplies
of natural gas covered under any expiring long-term contracts with gas purchased
on the spot market or under long-term or short-term contracts. The average daily
gas consumption of Electric Operations during 1998 was 696 billion British
thermal units (BBtu) with peak daily consumption of 1,511 BBtu. Electric
Operations' average cost of natural gas was $2.18 per million British thermal
units (MMBtu) in 1998, $2.60 per MMBtu in 1997 and $2.31 per MMBtu in 1996.
Although natural gas has been relatively plentiful in recent years,
available supplies are vulnerable to disruption due to weather conditions,
transportation constraints and other events. As a result of these factors,
supplies of natural gas may become unavailable from time to time, or prices may
increase rapidly in response to temporary supply constraints or other factors.
Coal and Lignite Supply. Electric Operations purchases approximately 80% of
the coal required to operate its four coal-fired units at the W. A. Parish
Electric Generating Station (W. A. Parish) under two long-term contracts from
mines in the Powder River Basin area of Wyoming. The first of these contracts
expires in 2010, and the other expires in 2011. Electric Operations obtains the
remaining coal required to operate these units under short-term contracts. The
majority of the coal purchased for W. A. Parish is currently transported under a
rail transportation contract with Burlington Northern Santa Fe Railroad; the
contract expires in March 2000. In 1997, Electric Operations completed
construction of a 10-mile rail line to connect its W. A. Parish coal-handling
facilities to Union Pacific Railroad Company rail lines. Shipments of coal
pursuant to a 1996 rail transportation contract with Union Pacific Railroad
Company commenced in 1997. During 1997 and 1998, Union Pacific Railroad Company
experienced significant delays in completing shipments of coal. To date these
delays have not had a material adverse impact on Electric Operations' generation
capability or its financial results of operations.
Electric Operations obtains the lignite used to fuel the two units of its
Limestone Electric Generating Station (Limestone) from a surface mine adjacent
to the plant. The Company owns the mining equipment, facilities and a portion of
the lignite reserves. The lignite reserves currently under lease and contract
are expected to be sufficient to provide substantially all of the lignite
requirements for Limestone through 2015.
Nuclear Fuel Supply. Fuel supply requirements for the South Texas Project
consist of (i) the acquisition of uranium concentrates, (ii) the conversion of
such concentrates into uranium hexafluoride, (iii) the enrichment of uranium
hexafluoride and (iv) the fabrication of nuclear fuel assemblies. The South
Texas Project has contracted for the raw materials and services necessary to
operate the plant through the following years:
<TABLE>
<S> <C>
Uranium.................................................................................... 2002(1)
Conversion................................................................................. 2002
Enrichment................................................................................. 2004(2)
Fabrication................................................................................ 2005
</TABLE>
- ----------
(1) Contracts provide for over 50% of the uranium concentrates required through
2002. The South Texas Project expects to obtain the balance of uranium
concentrates through future spot and medium-term contracts.
(2) Contracts provide for up to 100% of enrichment services through 2004, and
up to 60% of enrichment requirements through 2008. The South Texas Project
expects to obtain the balance of enrichment services through future spot,
medium- and long-term contracts.
5
<PAGE> 10
Although the Company and the other South Texas Project owners cannot predict the
future availability of uranium and related services, it is not anticipated,
based on current market conditions, that the South Texas Project will have
difficulty in obtaining fuel requirements for its remaining years of operation.
For information regarding assessments for spent fuel disposal, decontamination
and decommissioning costs, see Note 4 to the Company's Consolidated Financial
Statements.
Purchased Power Contracts. At December 31, 1998, Electric Operations had
two purchased power contracts covering 320 MW of firm capacity and associated
energy. These contracts have initial terms ending in 2005. Capacity payments
under firm purchased power commitments for the next three years are
approximately $22 million per year. The Company's two principal firm capacity
contracts contain provisions allowing Electric Operations to suspend or reduce
purchased power payments in the event that the Texas Utility Commission
disallows future recovery of these costs through Electric Operations' rates for
electric service. In addition, Electric Operations purchases power from various
qualifying facilities exercising their rights under the Public Utility
Regulatory Policies Act of 1978. Such purchases are generally at the discretion
of the qualifying facility, and are made pursuant to a pricing methodology
defined in Electric Operations' tariffs and approved by the Texas Utility
Commission. From time to time when market conditions dictate it, Electric
Operations also purchases power from various wholesale market participants
including qualifying facilities, exempt wholesale generators, power marketers
and other utilities. For additional information, see "Management's Discussion
and Analysis of Financial Condition and Results of Operations of the Company --
Results of Operations by Business Segment -- Electric Operations -- Fuel and
Purchased Power Expense -- Electric Operations" and Note 12(b) to the Company's
Consolidated Financial Statements.
6
<PAGE> 11
OPERATING STATISTICS OF ELECTRIC OPERATIONS
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------------------
1998 1997 1996
--------------- --------------- ---------------
<S> <C> <C> <C>
Electric Energy Generated and Purchased (Megawatt-Hours (MWH)):
Generated-- Net Station Output................................... 59,974,160 56,066,845 55,170,841
Purchased........................................................ 16,041,143 14,008,452 12,540,172
Net Interchange.................................................. (677) 841 1,486
------------- ------------- -------------
Total..................................................... 76,014,626 70,076,138 67,712,499
Company Use, Lost and Unaccounted for Energy..................... (3,281,851) (2,998,375) (3,002,774)
------------- ------------- -------------
Total Energy Sold......................................... 72,732,775 67,077,763 64,709,725
Electric Sales (MWH):
Residential...................................................... 21,090,164 19,365,892 19,048,238
Commercial....................................................... 16,329,354 15,474,761 14,640,762
Small Industrial(1).............................................. 11,801,292 11,439,753 11,727,500
Large Industrial(1).............................................. 14,805,199 14,380,499 13,519,845
Street Lighting-- Government and Municipal....................... 133,644 127,761 119,339
------------- ------------- -------------
Total Firm Retail Sales................................... 64,159,653 60,788,666 59,055,684
Other Electric Utilities......................................... 203,542 190,878 205,463
------------- ------------- -------------
Total Firm Sales.......................................... 64,363,195 60,979,544 59,261,147
Interruptible.................................................... 5,028,990 4,278,458 4,038,277
Off-System....................................................... 3,137,870 1,742,993 1,062,675
Unbilled......................................................... 202,720 76,768 347,626
------------- ------------- -------------
Total..................................................... 72,732,775 67,077,763 64,709,725
============= ============= =============
Number of Customers (End of Period):
Residential...................................................... 1,417,206 1,378,658 1,353,631
Commercial....................................................... 196,941 190,437 185,031
Small Industrial(1).............................................. 1,600 1,526 1,692
Large Industrial (Including Interruptible)(1).................... 137 132 126
Street Lighting-- Government and Municipal....................... 87 86 83
Other Electric Utilities (Including Off-System).................. 29 20 15
------------- ------------- -------------
Total..................................................... 1,616,000 1,570,859 1,540,578
============= ============= =============
Operating Revenue (Thousands of Dollars):
Residential...................................................... $ 1,786,662 $ 1,662,177 $ 1,603,591
Commercial....................................................... 1,108,328 1,065,917 986,591
Small Industrial(1).............................................. 637,124 616,419 611,495
Large Industrial(1).............................................. 534,814 529,718 473,451
Street Lighting-- Government and Municipal....................... 25,964 24,868 22,125
------------- ------------- -------------
Total Electric Revenue-- Firm Retail Sales................ 4,092,892 3,899,099 3,697,253
Other Electric Utilities......................................... 12,609 11,330 18,841
------------- ------------- -------------
Total Electric Revenue-- Firm Sales....................... 4,105,501 3,910,429 3,716,094
Interruptible.................................................... 114,574 108,053 97,164
Off-System....................................................... 87,510 39,724 25,995
------------- ------------- -------------
Total Electric Revenue.................................... 4,307,585 4,058,206 3,839,253
Miscellaneous Electric Revenues (including Unbilled Revenues).... 42,690 193,037 185,774
------------- ------------- -------------
Total..................................................... $ 4,350,275 $ 4,251,243 $ 4,025,027
============= ============= =============
Installed Net Generating Capability (KW) (End of Period)........... 14,092,370 14,040,370 13,960,370
Cost of Fuel (Cents per MMBtu):
Gas.............................................................. 218.4 259.9 231.3
Coal............................................................. 177.8 201.8 210.8
Lignite.......................................................... 119.1 108.4 111.1
Nuclear.......................................................... 48.0 54.2 61.6
Average................................................... 169.9 186.8 181.6
</TABLE>
- ----------
(1) For reporting purposes, customers of Electric Operations with an electric
demand in excess of 600 kilovolt-amperes are classified as industrial.
Small industrial customers typically are retail stores, office buildings,
universities and other customers not associated with large industrial
plants.
7
<PAGE> 12
NATURAL GAS DISTRIBUTION
Resources, through three of its unincorporated divisions, purchases,
transports, stores and distributes natural gas and provides natural gas utility
services to over 2.8 million residential, commercial and industrial customers in
six states, including the metropolitan areas of Minneapolis, Minnesota; Houston,
Texas; Little Rock, Arkansas; and Shreveport, Louisiana. The operations of
Natural Gas Distribution are regulated as gas utility operations in the
jurisdictions served by these divisions.
LOCAL DISTRIBUTION DIVISIONS
Reliant Energy Arkla. Reliant Energy Arkla provides natural gas
distribution services in approximately 621 communities in the States of
Arkansas, Louisiana, Oklahoma and Texas. The largest metropolitan areas served
by Reliant Energy Arkla are Little Rock, Arkansas and Shreveport, Louisiana. In
1998, approximately 69% of its total throughput was composed of retail sales of
gas and approximately 31% was attributable to transportation services. Sales to
residential and commercial customers in 1998 accounted for approximately 89% of
its total gas revenues and 64% of natural gas volumes sold or transported.
Reliant Energy Entex. Reliant Energy Entex provides natural gas
distribution services in approximately 502 communities in the States of
Louisiana, Mississippi and Texas. The largest metropolitan area served by
Reliant Energy Entex is Houston, Texas. In 1998, approximately 96% of its total
throughput was composed of retail sales of gas and approximately 4% was
attributable to transportation services. Sales to residential and commercial
customers in 1998 accounted for approximately 86% of its total gas revenues and
79% of natural gas volumes sold.
Reliant Energy Minnegasco. Reliant Energy Minnegasco provides natural gas
distribution services in approximately 243 communities in the State of
Minnesota. The largest metropolitan area served by Reliant Energy Minnegasco is
Minneapolis, Minnesota. In 1998, approximately 97% of its total throughput was
composed of retail sales of gas and approximately 3% was attributable to
transportation services. Sales to residential and commercial customers in 1998
accounted for approximately 90% of its total gas revenues and 86% of natural gas
volumes sold.
The demand for natural gas distribution services is seasonal in nature. In
1998, approximately 70% of Natural Gas Distribution's revenues were reported in
the first and fourth quarters. These patterns reflect the higher demand for
natural gas for heating purposes during those periods.
SUPPLY AND TRANSPORTATION
Reliant Energy Arkla. In 1998, Reliant Energy Arkla purchased approximately
23% of its natural gas supply from a subsidiary of Resources, Reliant Energy
Services, 55% pursuant to third party contracts (having terms varying from 3
months to 1 year) and 22% on the spot market. During 1998, Arkla's major third
party natural gas suppliers included Seagull Marketing Services, Inc., Marathon
Oil Company, Producers Energy Marketing, LLC, Aquila Energy Marketing
Corporation, PG&E Energy Trading--Gas Corporation and Oneok Gas Marketing
Company. Reliant Energy Arkla transports substantially all of its natural gas
supplies under contracts with the Company's interstate pipeline subsidiaries.
These contracts will expire in 2002.
Reliant Energy Entex. In 1998, Reliant Energy Entex purchased approximately
99% of its natural gas supply pursuant to term contracts (having terms varying
from one to five years) and 1% on the spot market. During 1998, Entex's major
natural gas suppliers were Enron Capital and Trade Resources Corp., Koch Gas
Services Company, Tejas Gas Corp. and KN Energy, Inc. Reliant Energy Entex
transports its natural gas supplies on both interstate and intrastate pipelines
under long-term contracts with terms varying from one to five years.
8
<PAGE> 13
Reliant Energy Minnegasco. In 1998, Reliant Energy Minnegasco purchased
approximately 75% of its natural gas supply pursuant to term contracts (having
terms varying from one to ten years) with more than 30 different suppliers and
25% on the spot market. Most of the natural gas volumes under long-term
contracts are committed under terms providing for delivery during the winter
heating season, November through March. During 1998, Reliant Energy Minnegasco
purchased approximately two-thirds of its natural gas requirements from four
suppliers: Pan-Alberta Gas Ltd., TransCanada Gas Services Inc., Duke Energy
Trading and Marketing, LLC and Reliant Energy Services. Reliant Energy
Minnegasco transports its natural gas supplies on various interstate pipelines
under long-term contracts with terms varying from five to ten years.
Reliant Energy Arkla and Reliant Energy Minnegasco make use of various
leased and owned natural gas storage facilities to meet peak-day requirements
and to manage the daily changes in demand due to changes in weather. Contracted
supplies and storage for Reliant Energy Minnegasco are also supplemented from
time to time with stored liquefied natural gas and propane-air plant production.
Although natural gas supplies have been relatively plentiful in recent
years, available supplies are subject to disruption due to weather conditions,
transportation constraints and other events. As a result of these factors,
supplies of natural gas may become unavailable from time to time or prices may
increase rapidly in response to temporary supply constraints or other factors.
INTERSTATE PIPELINES
Resources' interstate natural gas pipeline business (Interstate Pipelines)
is conducted through REGT and MRT, which are both wholly owned subsidiaries of
Resources.
Interstate Pipelines owns and operates approximately 8,200 miles of
transmission lines and six natural gas storage facilities located across the
following eight states in the south-central United States: Arkansas, Kansas,
Louisiana, Mississippi, Missouri, Oklahoma, Tennessee and Texas. Interstate
Pipelines stores, transports and delivers natural gas on behalf of various
shippers primarily to utilities, industrial customers and third party pipeline
interconnects.
In 1998, approximately 40% of Interstate Pipelines' total operating
revenues was attributable to services provided by REGT and MRT to Reliant Energy
Arkla and approximately 12% of its operating revenues was attributable to
services provided by MRT to Laclede Gas Company (Laclede), an unaffiliated
distribution company that provides natural gas utility service to the greater
St. Louis metropolitan area in Illinois and Missouri. An additional 11% of
Interstate Pipelines' operating revenues was attributable to the transportation
of gas marketed by Reliant Energy Services. Interstate Pipeline provides service
to Reliant Energy Arkla and Laclede under several long-term firm storage and
transportation agreements. The expiration dates for the service agreements with
Laclede range from October 1999 through May 2000. Interstate Pipelines and
Laclede are currently negotiating the terms and conditions of a proposed renewal
of these agreements. The service agreement with Reliant Energy Arkla is
scheduled to expire in March 2002.
The business and operations of Interstate Pipelines are affected by
seasonal changes in the demand for natural gas, the relative price of natural
gas in the Mid-Continent and Gulf Coast Natural Gas supply regions and, to a
lesser extent, general economic conditions.
9
<PAGE> 14
WHOLESALE ENERGY
The Company's Wholesale Energy Marketing and Generation segment (Wholesale
Energy) is engaged in the acquisition, development and operation of, and sales
of capacity and energy from, non-utility power generation facilities, wholesale
energy trading and marketing, and natural gas gathering businesses. The Company
formed this segment in 1998 in order to more effectively pursue synergies
existing between its unregulated power generation and wholesale energy trading
businesses.
POWER GENERATION
Power Generation participates in independent power markets through the
acquisition of existing power plants and the development of new power plants
(greenfield projects). Power Generation's business strategy is to develop a
commercial generation portfolio in key regions to support the Company's electric
and natural gas trading and marketing operations. Reliant Energy Services, the
segment's trading and marketing unit, supplies fuel to these generating plants
and sells electricity produced by the plants. In 1998, Power Generation
generated, and Reliant Energy Services sold, approximately 3 million MWHs of
electricity, substantially all of which sales were in the California
marketplace.
In April 1998, Power Generation acquired four natural gas-fired, electric
generating plants (2,276 MW) from Southern California Edison Company (SCE) for
approximately $230 million. In July 1998, Power Generation acquired another
generating plant (1,500 MW) from SCE for approximately $43 million. All of the
plants are located in southern California. Reliant Energy Services is acting as
the plants' exclusive power marketer and supplier of natural gas. In accordance
with the provisions of the asset sale agreements, Power Generation was required
to contract with SCE to operate and maintain the plants through April 2000.
Power Generation does, however, exercise management authority over the plants'
operations. For information on regulation of these units, see "Regulation -
Federal Energy Regulatory Commission" below.
Power Generation, through its subsidiaries, has under construction the
following power projects:
<TABLE>
<CAPTION>
PROJECT LOCATION INTEREST PROJECTED COMPLETION DATE
------- -------- -------- -------------------------
<S> <C> <C> <C>
El Dorado Project Boulder City, 50% Fourth Quarter of 1999
(492 MW gas-fired merchant plant) Nevada
Sabine Cogeneration Project Orange, 50% Fourth Quarter of 1999
(100 MW gas-fired cogeneration plant) Texas
</TABLE>
In 1998, Power Generation also announced plans for power projects in
Arizona, Illinois and Rhode Island with a combined capacity of 1,648 MW.
Negotiation of development contracts regarding these projects is underway.
The Company expects that Power Generation will continue to participate
actively in non-rate regulated power projects, including greenfield projects,
competitive auctions and other acquisitions of generation assets. The amount of
expenditures associated with these activities is dependent upon the nature and
extent of future project opportunities and commitments; however, some of these
expenditures could be substantial. Power Generation intends to finance a portion
of its non-rate regulated power projects through the proceeds from project
financings (financings where lenders limit their recourse for the payment of
amounts loaned to project revenues, equity investment and physical assets),
borrowings at subsidiaries and through equity investment and loans from the
Company and financing subsidiaries of the Company.
The successful completion of greenfield projects and other non-rate
regulated power projects is dependent upon a number of factors, which include,
among other things, risks associated with failures of siting, financing,
construction and permitting; failure to obtain governmental approvals;
termination of power sales contracts (if any) as a result of a failure to meet
certain construction milestones; and the uncertainties arising from the changing
regulatory system affecting Power Generation's markets. Many of the facilities
being acquired or developed by Power Generation are
10
<PAGE> 15
"merchant plants," that is, plants lacking dedicated offtake customers, making
such facilities sensitive to market and regulatory factors and other
considerations. For information with respect to a proposed investment in a
Netherlands wholesale generating company which was announced on March 10, 1999,
and would be made through subsidiaries of Power Generation, see Note 16(c) to
the Company's Consolidated Financial Statements.
ENERGY MARKETING AND RISK MANAGEMENT
Reliant Energy Services, a wholly owned subsidiary of Resources, buys,
sells and trades natural gas, electricity, certain emissions credits, crude oil,
coal and refined products. In addition, it offers physical and financial
wholesale energy marketing and price risk management products and services to a
variety of customers, including natural gas distribution companies,
municipalities, cooperatives, power plants, marketers, aggregators and large
volume industrial customers.
Reliant Energy Services purchases natural gas from a variety of suppliers
under daily, monthly, variable load and base load and term contracts that
include either market sensitive or fixed pricing provisions. Reliant Energy
Services sells natural gas under sales agreements that have varying terms and
conditions, most of which are intended to match seasonal and other changes in
demand. In 1998, Reliant Energy Services sold over 1,168 billion cubic feet
(BCF) of natural gas, substantially all of which was to non-affiliates.
Reliant Energy Services' natural gas marketing activities include
contracting to buy specified volumes of natural gas from suppliers at various
points of receipt to be supplied over a specified period of time; aggregating
natural gas supplies and arranging for their transportation; negotiating the
sale of specific volumes of natural gas over a specified period of time; and
matching natural gas receipts and deliveries based on volumes required by
customers. Additionally, Reliant Energy Services from time to time arranges for
the transportation of the natural gas it markets from the supplier receipt point
to the delivery point requested by the purchasers. Transportation arrangements
are made with affiliated and non-affiliated interstate and intrastate pipelines
through a variety of means, including short-term and long-term firm and
interruptible agreements.
Reliant Energy Services also enters into various short-term and long-term
firm and interruptible agreements for natural gas storage in order to offer peak
delivery services to satisfy winter heating and summer electric generating
demands. Such services are also intended to provide an additional level of
performance security and backup services to Reliant Energy Services' customers.
Reliant Energy Services sells electric power primarily to electric
utilities and other marketing companies. In 1998, Reliant Energy Services sold
over 65 million MW hours of electric power and 25 million MW hours in 1997.
Reliant Energy Services intends to seek to supply natural gas to, and purchase
electricity for resale from, non-regulated power plants in deregulated markets,
including generating plants currently owned or to be developed, acquired or
operated by Power Generation.
Additionally, Reliant Energy Services purchases and sells emissions
credits, crude oil, coal and refined products as part of its comprehensive
energy trading, marketing and risk management portfolio.
Reliant Energy Services uses derivative financial instruments to manage and
hedge its fixed-price purchase and sale commitments, to provide fixed-price
commitments as a service to its customers and suppliers, to reduce its exposure
relative to the volatility of the cash market prices and to protect its
investment in storage inventories. In 1998, Reliant Energy Services financially
settled on average over ll trillion British thermal units equivalents (TBtue)
per day of energy derivative financial instruments in its trading and price risk
management activities.
Although Reliant Energy Services generally attempts to balance its
fixed-price physical and financial purchase and sale obligations, commodity
price exposure often exists or is created due to the origination of new
transactions and the assessment of, and response to, changing market conditions.
Reliant Energy Services is accordingly exposed in such transactions to the risk
that fluctuating market prices may adversely affect its, the Company's and
Resources' financial position or results of operations. For additional
information with respect to the Company's and Resources' financial exposure to
derivative financial instruments, see Item 7A of this Form 10-K, Notes 1(r) and
2 to the Company's Consolidated Financial Statements and Notes 1(r) and 2 to
Resources' Consolidated Financial Statements.
11
<PAGE> 16
In addition to the risk associated with price movements, credit risk is
also inherent in Reliant Energy Services' trading, marketing and risk management
activities. Credit risk relates to the risk of loss resulting from the
nonperformance of contractual obligations by a counterparty. Reliant Energy
Services maintains credit policies intended to minimize overall credit risk with
regard to its counterparties. For additional information on the Company's credit
risk management, see Note 2 to the Company's Consolidated Financial Statements
and Note 2 to Resources' Consolidated Financial Statements.
The Company has established a Corporate Risk Oversight Committee, comprised
of corporate and business segment officers, to oversee all corporate price and
credit risks, including Reliant Energy Services' trading, marketing and risk
management activities. The Corporate Risk Oversight Committee's responsibilities
include reviewing the Company's and its subsidiaries' hedging, trading and price
risk management strategies, activities and limits and monitoring to ensure
compliance with the Company's risk management policies and procedures, as well
as trading limits established by the Company's board of directors. For
additional information regarding risk management accounting policies, see Note 2
to the Company's Consolidated Financial Statements and Note 2 to Resources'
Consolidated Financial Statements.
NATURAL GAS GATHERING
Reliant Energy Field Services, a wholly owned subsidiary of Resources,
provides natural gas gathering services, including related liquids extraction
and marketing activities. Reliant Energy Field Services operates approximately
4,000 miles of gathering pipeline which collect natural gas from more than 200
separate systems located in major producing fields in Arkansas, Louisiana,
Oklahoma and Texas.
INTERNATIONAL
International operations (International) includes the operations of Reliant
Energy International, a subsidiary of the Company that participates in the
privatization of foreign generating and distribution facilities and the
development and acquisition of foreign independent power projects, primarily in
Latin America. The international operations of Resources (Resources
International), which are managed by Reliant Energy International, are included
in International.
As of December 31, 1998, the Company's Consolidated Balance Sheets
reflected $1,127 million of foreign investments, a substantial portion of which
represents equity investments in foreign utility companies. The operations of
Resources International were not material to the 1998 results of operations of
International.
For a discussion of certain risks associated with international operations,
including the impact of currency fluctuations in countries such as Brazil, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Certain Factors Affecting Future Earnings of the
Company and its Subsidiaries -- Risks of International," "Quantitative and
Qualitative Disclosures About Market Risk -- Foreign Currency Exchange Rate
Risk" in Item 7A of this Form 10-K and Note 16(a) to the Company's Consolidated
Financial Statements.
MAJOR FOREIGN INVESTMENTS
Argentina. As of December 31, 1998, approximately 10% of International's
foreign investments was located in Argentina. In June 1998, Reliant Energy
International sold its 63% ownership interest in the electric utility serving La
Plata, Argentina. Reliant Energy International currently owns, through its
subsidiaries, a 100% interest in a corporation formed to develop, own and
operate a 160 MW cogeneration project (Argener) located at a steel plant near
San Nicolas, Argentina and a 90% interest in a utility in north-central
Argentina (EDESE). Argener commenced operations in November 1998.
12
<PAGE> 17
Brazil. As of December 31, 1998, approximately 35% of International's
foreign investments was located in Brazil. Reliant Energy International
indirectly owns 11.69% of the common stock of Light Servicos de Eletricidade
S.A., a publicly held Brazilian corporation (Light), which is the operator of an
integrated electric power and distribution system that serves a portion of the
state of Rio de Janeiro, Brazil, including the city of Rio de Janeiro. The
subsidiary of Reliant Energy International and the other winning bidders in the
government sponsored auction for Light formed a consortium whose aggregate
ownership interest of 50.44% represents a controlling interest in Light. In
April 1998, Light purchased 74.88% of the common stock of Metropolitana
Electricidade de Sao Paulo S.A. (Metropolitana), an electric distribution
company that serves the metropolitan area of Sao Paulo, Brazil.
Colombia. As of December 31, 1998, approximately 40% of International's
foreign investments was located in Colombia. In August 1998, Reliant Energy
International and Corporacion EDC S.A.C.A. (CEDC), jointly acquired, through
subsidiaries, 65% of the stock of two Colombian electric distribution companies,
Electricaribe and Electrocosta. The companies serve approximately 1.2 million
customers in the Atlantic coastal region of Colombia, including the cities of
Santa Marta, Barranquilla and Cartagena.
Additionally, Reliant Energy International and CEDC jointly hold a 56.7%
indirect controlling ownership interest in Empresa de Energia del Pacifico
S.A.E.S.P. (EPSA), an electric utility system serving the Valle del Cauca
province of Colombia, including the area surrounding the city of Cali. Reliant
Energy International itself has a 28.35% indirect ownership interest in EPSA. In
addition to its distribution facilities, EPSA owns 850 MW of electric generation
capacity. In December 1998, EPSA acquired an additional 56.4% interest in
Compania de Electricidad de Tulua (CET), increasing EPSA's total holdings to an
86.4% interest. CET, the electric utility in Tulua, in the center of the Valle
Del Cauca province, serves 37,000 customers and has three hydro-generating
units.
Resources International owns interests in four natural gas distribution
concessions under construction in Colombia. As of December 31, 1998, aggregate
expenditures incurred with respect to these concessions were approximately $5
million. Based on current projections, total additional expenditures for these
systems over the next five years are estimated to be approximately $5 million.
El Salvador. As of December 31, 1998, approximately 14% of International's
foreign investments was located in El Salvador. In early 1998, CEDC acquired
majority equity interests in three electric distribution systems located in
northern and eastern El Salvador, including the city of San Salvador. On June
30, 1998, CEDC closed the sale of approximately half of its interests in
the systems to a subsidiary of Reliant Energy International for
approximately $150 million.
India. In July 1998, a subsidiary of Reliant Energy International, together
with various other investors, completed development of a coke calcining and
power generation facility in India. Reliant Energy International's total
investment in this project is approximately $12 million.
Mexico. In January 1998, Resources International and a local investor
accepted an award of a 30-year concession from the Mexican government to build,
operate and maintain a natural gas distribution system in northeastern Mexico.
Based on current projections, the project is expected to be completed in 2002 at
a total cost of approximately $15 million.
CORPORATE
The Company's Corporate business segment includes (i) the operations of
Reliant Energy Retail which conducts retail energy marketing services; (ii)
various office buildings and other real estate used in the Company's and its
subsidiaries' business operations; (iii) unallocated corporate costs; and (iv)
inter-unit eliminations. Reliant Energy Retail, a wholly owned subsidiary of
Resources, markets natural gas and related energy services to industrial
customers who are served by large local gas distribution companies or connected
to interstate and intrastate pipelines offering unbundled transportation
services. Included in Reliant Energy Retail's retail marketing operations are
three intrastate pipeline subsidiaries of Resources that market and deliver
natural gas to large volume customers at market-based rates. Corporate
13
<PAGE> 18
also includes the Company's retail marketing operations, which offer energy
products and services to customers in and outside the Company's and Resources'
regulated service areas. For additional information about Corporate, see Note 15
to the Company's Consolidated Financial Statements.
REGULATION
The Company and Resources and their respective subsidiaries are subject to
regulation by various federal, state, local and, in the case of Reliant Energy
International, foreign governmental agencies, including those regulations
described below.
PUBLIC UTILITY HOLDING COMPANY ACT
Holding Company Status. The Company is both a holding company and an
electric utility as defined in the 1935 Act; however, it is exempt from
regulation as a holding company based on an order granted in July 1997 by the
Securities and Exchange Commission (SEC) under Section 3(a)(2) of the 1935 Act.
Although Resources is a natural gas utility company as defined under the 1935
Act, it is not a holding company within the meaning of the 1935 Act. The Company
and Resources remain subject to regulation under the 1935 Act with respect to
the acquisition of certain voting securities of other domestic public utility
companies and utility holding companies.
Regulation of Investments in Exempt Wholesale Generation Facilities.
Companies, like Power Generation, which own facilities used exclusively for the
generation of electricity for sale at wholesale, are not deemed electric utility
companies under the 1935 Act, provided certain conditions are met. The
generating units owned by Power Generation's subsidiaries qualify as exempt
wholesale generators under these provisions. However, such companies may be
subject to regulation as public utilities under the Federal Power Act. For
information regarding the regulation of two of Power Generation's California
facilities under jurisdiction of the Federal Energy Regulatory Commission
(FERC), see "--Federal Energy Regulatory Commission" below.
Regulation of Foreign Utility Company Investments. Section 33(a)(1) of the
1935 Act exempts foreign utility company affiliates of the Company and Resources
from regulation as "public utility companies," thereby permitting the Company
and Resources to invest in foreign utility companies without registration under
the 1935 Act as a holding company or approval by the SEC thereunder. The
exemption, however, is subject to the SEC's having received from each state
commission having jurisdiction over the retail rates of any electric or gas
utility company affiliated with the Company or Resources, a certification to the
effect that such commission has the authority and resources to protect
ratepayers subject to its jurisdiction and that such commission intends to
exercise its authority. The Texas Utility Commission and the state regulatory
commissions exercising jurisdiction over Resources (Arkansas, Louisiana,
Minnesota, Mississippi, Oklahoma and Texas) have provided such a certification
to the SEC subject, however, to the right of such commissions to revise or
withdraw their certifications as to any future acquisition of a foreign utility
company. The Texas Utility Commission and the state regulatory commissions of
Arkansas and Minnesota have imposed limitations on the amount of investments by
utility companies (including the Company and Resources) in foreign utility
companies and, in certain cases, foreign electric wholesale generating
companies. These limitations are based upon the Company's consolidated net
worth, retained earnings and capitalization, respectively.
Subject to certain limited exceptions, Section 33(f)(1) of the 1935 Act
also prohibits any public utility from issuing any security for the purpose of
financing the acquisition, ownership or operation of a foreign utility company,
or assuming any obligation or liability in respect of any security of a foreign
utility company.
Proposals to Repeal the 1935 Act. Several bills have been introduced in
Congress that would repeal the 1935 Act. Repeal or significant modification to
the 1935 Act could have a significant impact on the Company and the electric
utility industry. At this time, however, the Company is not able to predict the
outcome of any bills to repeal the 1935 Act or the outlook for additional
legislation in 1999.
14
<PAGE> 19
FEDERAL ENERGY REGULATORY COMMISSION
The transportation and sale for resale of natural gas in interstate
commerce is subject to regulation by the FERC under the Natural Gas Act (NGA)
and, to a lesser extent, the Natural Gas Policy Act of 1978, as amended (NGPA).
The FERC has jurisdiction over, among other things, the construction of pipeline
and related facilities used in the transportation and storage of natural gas in
interstate commerce, including the extension, expansion or abandonment of such
facilities. The rates charged by interstate pipelines for interstate
transportation and storage services are also regulated by the FERC.
REGT and MRT periodically file applications with the FERC for changes in
their rates and charges designed to allow them to recover their costs of
providing service to customers (to the extent allowed by prevailing market
conditions), including a reasonable rate of return. These rates are normally
allowed to become effective after a suspension period, and in certain cases are
subject to refund under applicable law, until such time as FERC issues an order
on the allowable level of rates. REGT is currently operating under rates
approved by the FERC which took effect in February 1995, and MRT is currently
providing services pursuant to a negotiated rate settlement approved by the FERC
in October 1997.
In July 1998, FERC issued a Notice of Proposed Rulemaking directed at its
regulation of short-term natural gas transportation services, which are services
sold for periods of less than one year. The proposals in this rulemaking, if
adopted, would modify in various ways the current market practices for buying
and selling these short-term services. As a companion to this rulemaking, the
FERC also issued a Notice of Inquiry for the purpose of studying the effect of
its existing policies on the market for long-term natural gas transportation
services. FERC asked for comments from all industry segments on its two notices.
If adopted, the Company expects the FERC initiatives will broadly affect all
market participants. The Company and Resources are not able to determine at this
time the ultimate outcome of FERC's initiatives.
The California plants owned by Power Generation are subject to FERC
jurisdiction and regulation. The FERC generally permits the California plants to
make sales at market based rates and has waived most of the regulatory
requirements otherwise applicable to regulated public utilities under the
Federal Power Act. Special rules, however, apply to the two California plants
which have been designated as "reliability must-run" facilities by the
California Independent System Operator Corporation. Units at these plants must
provide electric service to the system operator when required for reliability
purposes at rates and under terms and conditions regulated by the FERC. At other
times, the plants may sell at market based rates.
Reliant Energy Services is also subject to jurisdiction under both the NGA
and the Federal Power Act. As a gas marketer, Reliant Energy Services makes
sales of natural gas in interstate commerce at wholesale pursuant to a blanket
certificate issued by the FERC, but the FERC does not otherwise regulate the
rates, terms or conditions of these gas sales. Reliant Energy Services is a
"public utility" under the Federal Power Act, and its wholesale sales of
electricity in interstate commerce are subject to a FERC-filed rate schedule
that authorizes Reliant Energy Services to make sales at negotiated,
market-based rates. Reliant Energy Services' market-based rate tariffs are filed
with the FERC. The FERC also imposes certain restrictions on Reliant Energy
Services' transactions with Electric Operations and with REGT and MRT, including
a prohibition on the receipt of goods or services on a preferential basis.
Similar restrictions apply to transactions between Reliant Energy Services and
Electric Operations under the Public Utility Regulatory Act of 1995 (now the
Texas Utilities Code).
15
<PAGE> 20
STATE AND LOCAL UTILITY REGULATIONS
Electric Operations. The Company conducts its electric utility operations
under a certificate of convenience and necessity granted by the Texas Utility
Commission. The certificate of convenience and necessity covers the present
service area and facilities of Electric Operations. In addition, the Company
holds non-exclusive franchises to provide electric service within the
incorporated municipalities in the service territory of Electric Operations.
None of these franchises expires before 2007.
Under the Texas Utilities Code, the Texas Utility Commission has original
jurisdiction over electric rates and services in unincorporated areas of the
State of Texas and in the incorporated municipalities that have relinquished
original jurisdiction. Original jurisdiction over electric rates and services in
the remaining incorporated municipalities served by Electric Operations is
exercised by such municipalities, including the city of Houston, but the Texas
Utility Commission has appellate jurisdiction over electric rates and services
within those incorporated municipalities. For additional information, including
information about the status of legislation governing competition in the retail
electric market in Texas, see "Management's Discussion and Analysis of Financial
Condition and Results of Operation of the Company -- Certain Factors Affecting
Future Earnings of the Company and Its Subsidiaries -- Competition and
Restructuring of the Electric Utility Industry."
Natural Gas Distribution Operations. In almost all communities in which
Natural Gas Distribution provides service, Resources operates under franchises,
certificates or licenses obtained from state and local authorities. The terms of
the franchises, with various expiration dates, typically range from ten to
thirty years. None of Natural Gas Distribution's material franchises expires
before 2005. In most cases, franchises to provide natural gas utility services
are not exclusive.
Substantially all of Natural Gas Distribution's retail sales are subject to
traditional cost-of-service regulation at rates regulated by the relevant state
public service commissions and, in Texas, by municipalities served by Natural
Gas Distribution. None of Natural Gas Distribution's local distribution
companies is currently a party to any pending rate proceeding.
NUCLEAR REGULATORY COMMISSION
Under the 1954 Atomic Energy Act and the 1974 Energy Reorganization Act,
operation of nuclear plants is extensively regulated by the United States
Nuclear Regulatory Commission (NRC), which has broad power to impose licensing
and safety requirements. In the event of non-compliance, the NRC has the
authority to impose fines or shut down nuclear plants, or both, depending upon
its assessment of the severity of the situation, until compliance is achieved.
The 1980 Federal Low-Level Radioactive Waste Policy Act directed states to
assume responsibility for the disposal of low-level nuclear waste generated
within their borders. Under this Act, states may combine with other states and
seek consent from the U.S. Congress for regional compacts to construct and
operate low-level nuclear waste sites. Only two sites (the Envirocare facility
in Utah and the Barnwell facility in South Carolina) are currently licensed and
available to the South Texas Project for low-level waste disposal. The South
Texas Project has entered into a contract with the operator of the Barnwell
facility to dispose of all of the South Texas Project's low-level nuclear waste
through June 1999.
16
<PAGE> 21
A bill establishing an interstate compact among Texas, Maine and Vermont
was signed into law in September 1998. The compact limits access to a Texas
waste disposal facility to the three compact members and provides for
contributions from Maine and Vermont toward the construction of such a facility.
In October 1998, the Texas Natural Resource Conservation Commission (TNRCC)
denied the application of the Texas Low-Level Radioactive Waste Disposal
Authority (Waste Disposal Authority) to build and operate a low-level waste
disposal facility in Hudspeth County, Texas. In the event the Barnwell facility
stops accepting waste before a Texas site is opened, the South Texas Project
would store its waste in an interim storage facility located at the nuclear
plant. The plant currently has storage capacity for at least five years of
low-level nuclear waste generated by the project.
The Waste Disposal Authority is currently authorized to assess a planning
and implementation fee upon waste generators to fund development of the proposed
Texas disposal facility. However, the Texas legislature is considering several
measures that could change the Company's share of this assessment from prior
years. In 1998, the Company's share of the Waste Disposal Authority's fiscal
year assessment was $0.7 million.
For information regarding the NRC's regulation of nuclear decommissioning
trust funds and the NRC's obligation to provide storage for nuclear fuel, see
Note 4 of the Company's Consolidated Financial Statements.
ENVIRONMENTAL MATTERS
The Company and its subsidiaries are subject to a number of federal, state
and local environmental requirements that govern the discharge of emissions into
the air and water and regulate the handling of solid and hazardous waste. The
Company and its subsidiaries have incurred substantial expenditures in the past
to comply with these requirements and anticipate that further expenditures will
be incurred in the future.
A provision of the Federal Clean Air Act (Clean Air Act) affecting electric
power producers is the Acid Rain Program, which is designed to reduce emissions
of sulfur dioxide (SO2) from generating units. The program requires that after a
certain date an electric power producer must have been granted a regulatory
"allowance" for each ton of SO2 emitted from its facilities. Allowances have
been distributed to utilities by the Environmental Protection Agency (EPA) based
on their historical operations. If a utility is not allocated sufficient
allowances to cover its future SO2 emissions, it must either purchase allowances
or reduce its emissions of SO2. Electric Operations believes it holds sufficient
allowances for continued operations of its facilities for the foreseeable
future, including sufficient allowances to meet the Phase II (year 2000 and
later) requirements of the Clean Air Act.
Provisions of the Clean Air Act dealing with urban air pollution require
establishing new emission limitations for oxides of nitrogen (NOx) from existing
sources. The limitations applicable to Electric Operations' generating units in
the Houston, Texas area were established by the TNRCC and require implementation
by November 1999. In addition, Governor Bush of Texas has proposed that
"grandfathered" emission units (units constructed prior to permitting
requirements) voluntarily secure permits from the TNRCC and accomplish emission
reductions. Electric Operations has voluntarily committed to seek permits for
all such units, and will reduce NOx emissions from these units accordingly.
As a result of the new regulatory requirements and its voluntary
commitments, Electric Operations incurred approximately $7 million in 1998 for
NOx emission reductions at its Texas facilities and estimates that it will
expend approximately $8 million in 1999 and $10 million in 2000 for NOx
controls. Current TNRCC analyses indicate that further NOx reductions will be
required after 2000 to attain the prescribed ozone standard in the Houston area.
However, neither the timing nor the magnitude of possible future reduction
requirements has been identified at this time.
Various NOx emission reduction initiatives and emission credit purchases
were made in association with the acquisition of generation assets by Power
Generation in California. Approximately $1 million is anticipated to be spent on
continuous emission monitoring system upgrades of the Southern California
generating units in 1999.
17
<PAGE> 22
The EPA has issued regulations for State Implementation Plan development to
implement NOx reductions in 22 states, including Illinois and Rhode Island;
however, it is not anticipated that current regulations or implementation of
these plans would have a material impact on the Company's or Resources'
facilities.
The Clean Air Act also required a study to determine if additional
regulations are needed to improve visibility in the southwestern United States.
The Company does not expect that this study will require the installation of
additional pollution controls on the Company's and its subsidiaries' generating
units, including the generating units acquired by, or expected to be completed
by, Power Generation.
The EPA was directed by the Clean Air Act to perform a study of the risk to
public health from emissions of toxic air pollutants from power plants, and to
regulate such emissions as necessary. The EPA issued a report to Congress in
February 1998. The report makes no determination as to the need to issue
regulations applicable to the utility industry, and such a determination is not
expected until the National Academy of Science completes a review of studies in
mid-2000. It is, therefore, not possible to make any determination as to the
potential need for additional controls on emissions from the Company's or
Resources' facilities.
Concern about possible increases in the earth's temperature has resulted in
an international treaty to control emissions of gases, including those generated
in the course of power production and distribution which are believed to
contribute to the condition. The treaty, known as the Kyoto Protocol, has not
been ratified by the United States, and no current regulations are applicable to
the Company's or Resources' facilities in the United States. However, the Kyoto
Protocol could have an impact on the Company's international operations.
The Company's and Resources' expenditures associated with respect to
permits, registrations and authorizations for operation of facilities under the
statutes regulating the discharge of pollutants into surface water, and for the
handling and disposal of solid wastes have not been, and are not expected to be
material.
The issue of whether exposure to electric and magnetic fields (EMFs) may
result in adverse health effects or damage to the environment continues to be
debated. EMFs are produced by all devices which carry or use electricity,
including home appliances as well as electric transmission and distribution
lines. Results of studies concerning the effect of EMFs have been inconclusive
and EMFs are not the subject of any regulations affecting the Company or
Resources or their respective subsidiaries. However, lawsuits have arisen in
several states (including Texas) against electric utilities and others alleging
that the presence or use of electric power transmission and distribution lines
has an adverse effect on health and/or property values.
For a discussion of specific environmental contingencies for the Company
and Resources, projected expenditures in connection with environmental matters,
and a quantification of costs associated with these matters, see "Management's
Discussion and Analysis of Financial Condition and Results of Operations of the
Company -- Certain Factors Affecting Future Earnings of the Company and its
Subsidiaries -- Environmental Expenditures," Note 12(h) to the Company's
Consolidated Financial Statements and Note 8(g) to Resources' Consolidated
Financial Statements.
EMPLOYEES
As of December 31, 1998, the Company and its subsidiaries had 12,916
full-time employees. The following table sets forth information about the
Company's and Resources' employees by business segment as of such date:
<TABLE>
<S> <C>
Electric Operations............................................................................... 6,416
Natural Gas Distribution.......................................................................... 5,005
Interstate Pipeline............................................................................... 578
International..................................................................................... 70
Wholesale Energy.................................................................................. 374
Corporate......................................................................................... 473
--------
Total............................................................................................. 12,916
========
</TABLE>
18
<PAGE> 23
The number of employees of the Company and its subsidiaries who are represented
by unions or other collective bargaining groups include (i) Electric Operations,
2,779; (ii) Natural Gas Distribution, 1,524; and (iii) Wholesale Energy, 13.
EXECUTIVE OFFICERS OF THE COMPANY
AS OF MARCH 15, 1999
<TABLE>
<CAPTION>
OFFICER
NAME AGE(1) SINCE PRESENT POSITION
- ----------------------------- -------- --------- --------------------------------------------------
<S> <C> <C> <C>
DON D. JORDAN 66 1971 Chairman and Chief Executive Officer and
Director
R. STEVE LETBETTER 50 1978 President and Chief Operating Officer and
Director
LEE W. HOGAN 54 1990 Executive Vice President and Director
HUGH RICE KELLY 56 1984 Executive Vice President, General Counsel and
Corporate Secretary
STEPHEN W. NAEVE 51 1988 Executive Vice President and Chief Financial
Officer
CHARLES M. OGLESBY 45 1997 Chief Executive Officer, Reliant Energy
Wholesale Group
JOE BOB PERKINS 38 1996 President and Chief Operating Officer, Reliant
Energy Wholesale Group
DAVID M. MCCLANAHAN 49 1986 President and Chief Operating Officer, Reliant
Energy Delivery Group
MARY P. RICCIARDELLO 43 1993 Vice President and Comptroller
</TABLE>
19
<PAGE> 24
- -----------------
(1) As of December 31, 1998
Mr. Jordan has served as Chairman and Chief Executive Officer of the Company
since 1982. He has been a director of the Company since 1974. He has served in
various executive officer capacities with the Company and its subsidiaries since
1971.
Mr. Letbetter has served as President and Chief Operating Officer of the Company
since 1993. He has been a director of the Company since 1995. He has served in
various executive officer capacities with the Company and its subsidiaries since
1978.
Mr. Hogan has served as an Executive Vice President of the Company since 1997.
He has been a director of the Company since 1995. He has served in various
executive officer capacities with the Company and its subsidiaries since 1990,
including President and Chief Operating Officer of Reliant Energy International
Inc. between 1993 and 1997.
Mr. Kelly has served as Executive Vice President, General Counsel and Corporate
Secretary of the Company since 1997. Between 1984 and 1997, he served as Senior
Vice President, General Counsel and Corporate Secretary of the Company.
Mr. Naeve has served as Executive Vice President and Chief Financial Officer
with the Company since 1997. Between 1996 and 1997, he served as Senior Vice
President and Chief Financial Officer of the Company. He has served in various
executive officer capacities with the Company and its subsidiaries since 1984,
including Vice President - Strategic Planning and Administration between 1993
and 1996.
Mr. Oglesby has served as Chief Executive Officer - Reliant Energy Wholesale
Group since 1998. He served as Senior Vice President of the Company and
President and Chief Operating Officer - Trading & Transportation Group between
1997 and 1998. Between 1995 and 1997, he served as President - NorAm Trading and
Transportation Group. Between 1994 and 1995, he served as Vice President of
Coastal Corporation and President and Chief Executive Officer of Coastal Gas
Services Company.
Mr. Perkins has served as President and Chief Operating Officer, Reliant Energy
Wholesale Group and as President and Chief Operating Officer, Reliant Energy
Power Generation, Inc. since 1998. In 1998, Mr. Perkins served as President and
Chief Operating Officer of HI Power Generation Group. Between 1996 and 1998, Mr.
Perkins served as Vice President - Corporate Planning and Development. Prior to
joining the Company, he served as Vice President of Business Development and
Corporate Secretary of Coral Energy Resources, L.P. Between 1995 and 1996, he
served as Vice President and General Manager of Coral Power, L.L.C. Between 1994
and 1995, he was Director of Business Development for Tejas Gas Corporation.
Mr. McClanahan was appointed President and Chief Operating Officer of the
Reliant Energy Delivery Group in February 1999. Previously, he served as
President and Chief Operating Officer of the Reliant Energy HL&P division
between 1997 and 1999. He has served in various executive officer capacities
with the Company and its subsidiaries since 1986, including Group Vice President
- - Finance and Regulatory Relations between 1993 and 1996.
Ms. Ricciardello has served as Vice President and Comptroller of the Company
since 1996. She has served in various executive officer capacities of the
Company and its subsidiaries since 1993.
20
<PAGE> 25
ITEM 2. PROPERTIES.
CHARACTER OF OWNERSHIP
The principal properties of the Company, Resources and their respective
subsidiaries are owned in fee, except that most electric lines and gas mains are
located, pursuant to easements and other rights, in public roads or on land
owned by others.
Substantially all of the real estate, electric distribution system
properties, buildings and franchises owned directly by the Company (excluding
real estate and other properties of subsidiaries of the Company) are subject to
a lien created under a Mortgage and Deed of Trust dated as of November 1, 1944
(as supplemented, Mortgage) between the Company and South Texas Commercial
National Bank of Houston (Chase Bank of Texas, National Association, as
Successor Trustee). The lien of the Mortgage excludes cash, stock in
subsidiaries and certain other assets. Additionally, substantially all
properties of the subsidiaries of International and Power Generation that own
interests in operating plants are subject to liens of creditors of the
respective subsidiaries.
ELECTRIC OPERATIONS
All of the electric generating stations and other operating properties of
Electric Operations are located in the State of Texas.
Electric Generating Stations. As of December 31, 1998, the Company owned 12
electric generating stations (62 generating units) with a combined turbine
nameplate rating of 13,554,608 KW, including a 30.8% interest in one nuclear
generating station (two units) with a combined turbine nameplate rating of
2,623,676 KW.
South Texas Project. The Company is one of four owners of the South Texas
Project, a nuclear generating plant consisting of two 1,250 MW generating units
in which the Company has a 30.8% ownership interest.
Substations. As of December 31, 1998, the Company owned 213 major
substation sites (240 substations) having a total installed rated transformer
capacity of 53,413 Mva, including a 30.8% interest in one major substation with
an installed rated transformer capacity of 3,080 Mva.
Electric Lines -- Overhead. As of December 31, 1998, the Company owned
25,154 pole miles of overhead distribution lines and 3,606 circuit miles of
overhead transmission lines, including 502 circuit miles operated at 69,000
volts, 2,059 circuit miles operated at 138,000 volts and 1,044 circuit miles
operated at 345,000 volts.
Electric Lines -- Underground. As of December 31, 1998, the Company owned
10,780 circuit miles of underground distribution lines and 12.6 circuit miles of
underground transmission lines, including 4.5 circuit miles operated at 69,000
volts and 8.1 circuit miles operated at 138,000 volts.
NATURAL GAS DISTRIBUTION
Resources' approximately 55,000 linear miles of gas distribution mains vary
in size from one-half inch to 24 inches in diameter. Generally, in each of the
cities, towns and rural areas served by Natural Gas Distribution, Resources owns
the underground gas mains and service lines, metering and regulating equipment
located on customers' premises and the district regulating equipment necessary
for pressure maintenance. With a few exceptions, the measuring stations at which
Resources receives gas from its suppliers are owned, operated and maintained by
others, and the distribution facilities of Resources begin at the outlet of the
measuring equipment. These facilities, including odorizing equipment, are
usually located on the land owned by suppliers.
21
<PAGE> 26
INTERSTATE PIPELINE
Resources owns and operates, through REGT and MRT, approximately 8,200
miles of transmission lines and transportation service to various shippers
across eight states in the south-central and midwestern United States. Resources
or its subsidiaries also own and operate six storage fields with a combined
daily deliverability of approximately 1.2 BCF per day and a combined working gas
capacity of approximately 51.8 BCF. Most of Interstate Pipelines' storage
operations are in north Louisiana and Oklahoma.
WHOLESALE ENERGY
Resources, through its subsidiaries, owns and operates gathering pipelines
which collect gas from more than 200 separate systems located in major producing
fields in Arkansas, Louisiana, Oklahoma and Texas.
As of December 31, 1998, Wholesale Energy owned five electric generating
stations (15 generating units) with a combined nameplate rating of 3,906 MW. For
additional information regarding the properties of Power Generation, see
"Business -- Wholesale Energy" in Item 1 of this Form 10-K, which information is
incorporated herein by reference.
INTERNATIONAL
For information regarding the investments of International, see "Business
- -- International" in Item 1 of this Form 10-K.
OTHER
For information regarding the properties of Corporate, see "Business --
Corporate" in Item 1 of this Form 10-K.
22
<PAGE> 27
ITEM 3. LEGAL PROCEEDINGS.
(a) Company.
For a description of certain legal and regulatory proceedings affecting the
Company, see Notes 3(b), 12(h) and 12(i) to the Company's Consolidated Financial
Statements, which notes are incorporated herein by reference.
(b) Resources.
For a description of certain legal and regulatory proceedings affecting
Resources, see Note 8(g) to Resources' Consolidated Financial Statements, which
note is incorporated herein by reference.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
None.
23
<PAGE> 28
PART II
ITEM 5. MARKET FOR THE COMPANY'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS.
The Company's Common Stock, which at March 11, 1999 was held of record by
approximately 85,534 shareholders, is listed on the New York and Chicago Stock
Exchanges (symbol: REI). All of Resources' common stock is held by the Company.
The following table sets forth the high and low sales prices of the
Company's Common Stock on the composite tape during the periods indicated, as
reported by The Wall Street Journal, and the dividends declared for such
periods. Dividend payout was $1.50 per share for 1998 and 1997, respectively.
The dividend declared during the fourth quarter of 1998 is payable in March
1999.
<TABLE>
<CAPTION>
MARKET PRICE DIVIDEND
----------------------------- DECLARED
HIGH LOW PER SHARE
-------------- -------------- --------------
<S> <C> <C> <C>
1998
First Quarter........................................................ $ 0.375
January 16......................................................... $ 25
March 31........................................................... $ 28 15/16
Second Quarter....................................................... $ 0.375
May 20............................................................. $ 27 5/16
June 24............................................................ $ 32
Third Quarter........................................................ $ 0.375
August 7........................................................... $ 26 5/8
September 30....................................................... $ 32
Fourth Quarter....................................................... $ 0.375
October 12......................................................... $ 29 7/16
November 16........................................................ $ 33 3/8
1997
First Quarter........................................................ $ 0.375
February 25........................................................ $ 23 5/8
March 21........................................................... $ 20 5/8
Second Quarter....................................................... $ 0.375
April 18........................................................... $ 18 7/8
May 6.............................................................. $ 23 5/8
Third Quarter........................................................ $ 0.375
August 7........................................................... $ 22 1/8
August 28.......................................................... $ 20 1/8
Fourth Quarter....................................................... $ 0.375
December 31........................................................ $ 27 1/4
October 28......................................................... $ 20 3/4
</TABLE>
The closing market price of the Company's Common Stock on December 31, 1998
was $32 1/16 per share.
Future dividends will be subject to determination based upon the results of
operations and financial condition of the Company, the Company's future business
prospects, any applicable contractual restrictions and such other factors as the
Company's Board of Directors considers relevant. For information regarding
restrictions on the payment of dividends in the Company's credit agreements, see
Note 8(c) of the Notes to the Company's Consolidated Financial Statements.
24
<PAGE> 29
ITEM 6. SELECTED FINANCIAL DATA OF THE COMPANY.
The following table sets forth selected financial data with respect to the
Company's consolidated financial condition and results of consolidated
operations and should be read in conjunction with the Company's Consolidated
Financial Statements and the related notes in Item 8 of this Form 10-K. Certain
amounts from prior years have been reclassified to conform with the 1998
presentation. Such reclassifications do not affect earnings. In July 1995, the
Company sold its former cable television subsidiary, the operations of which
were accounted for as discontinued operations.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------------------------------------------------
1998 1997(1) 1996 1995 1994
-------------- -------------- -------------- -----------------------------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
Revenues $ 11,488,464 $ 6,878,225 $ 4,095,277 $ 3,729,271 $ 3,752,573
------------ ------------ ------------ ------------ ------------
Income (loss) from continuing operations
before cumulative effect of change in
accounting(2).......................... $ (141,092) $ 421,110 $ 404,944 $ 397,400 $ 423,985
Gain on sale of cable television
subsidiary............................. 708,124
Loss from discontinued operations........ (16,524)
Cumulative effect of change in
accounting(3).......................... (8,200)
Preferred dividends...................... 390 162
------------ ------------ ------------ ------------ ------------
Net income (loss)(2)..................... $ (141,482) $ 420,948 $ 404,944 $ 1,105,524 $ 399,261
============ ============ ============ ============ ============
Basic and diluted earnings (loss) per
common share(4):
Continuing operations before
cumulative effect of change in
accounting(2)........................ $ (.50) $ 1.66 $ 1.66 $ 1.60 $ 1.72
Gain on sale of cable television
subsidiary............................. 2.86
Loss from discontinued operations...... (.07)
Cumulative effect of change in
accounting(3).......................... (.03)
------------ ------------ ------------ ------------ ------------
Basic and diluted earnings (loss) per
common share(2) (4).................... $ (.50) $ 1.66 $ 1.66 $ 4.46 $ 1.62
Cash dividends declared per common
share(4)............................... $ 1.50 $ 1.50 $ 1.50 $ 1.50 $ 1.50
Dividend payout ratio from continuing
operations............................. 96% 89% 94% 87%
Return on average common equity(5) (6)... (3.1%) 9.7% 10.2% 29.5% 12.0%
Ratio of earnings from continuing
operations to fixed charges before
cumulative effect of change in
accounting(7).......................... 2.41 2.76 2.71 2.89
At year-end:
Book value per common share(4)......... $ 15.16 $ 17.28 $ 16.41 $ 16.61 $ 13.64
Market price per common share(4)....... $ 32.06 $ 26.75 $ 22.63 $ 24.25 $ 17.82
Market price as a percent of book
value................................ 211% 155% 138% 146% 131%
At year-end:
Total assets of continuing operations.. $ 19,138,522 $ 18,445,606 $ 12,287,857 $ 11,819,606 $ 10,784,095
Net assets of discontinued operations.. 618,982
------------ ------------ ------------ ------------ ------------
Total assets.................... $ 19,138,522 $ 18,445,606 $ 12,287,857 $ 11,819,606 $ 11,403,077
============ ============ ============ ============ ============
Long-term obligations, including
current maturities-continuing
operations(8)........................ $ 7,540,434 $ 5,831,356 $ 3,254,413 $ 3,692,173 $ 3,737,908
Long-term obligations, including
current maturities included in net
assets of discontinued operations.... 504,580
Capitalization from continuing
operations:
Common stock equity.................. 36% 46% 53% 50% 44%
Cumulative preferred stock (including
current maturities)................ 2% 5% 7%
Long-term debt (including current
maturities)(8)..................... 64% 54% 45% 45% 49%
</TABLE>
25
<PAGE> 30
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------------------------------------------------
1998 1997(1) 1996 1995 1994
------------ ------------ -------------- -------------- -------------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
Capital expenditures:
Purchase of Resources, net of cash
acquired........................... $ 1,422,672
Electric Operations' capital and
nuclear fuel expenditures
(excluding AFUDC)(9)............... $ 428,611 234,068 $ 314,934 $ 296,635 $ 412,899
Natural Gas Distribution............. 161,735 61,078
Interstate Pipelines................. 59,358 16,304
Wholesale Energy (excluding
capitalized interest).............. 363,792 14,038
International (excluding capitalized
interest).......................... 427,232 223,807 493,179 49,835 7,087
Corporate............................ 30,166 23,899 13,446 4,643 13,562
Cable television additions and other
cable-related investments -
discontinued....................... 47,601 84,071
Corporate headquarters expenditures
(excluding capitalized
interest)(9)....................... 5,308 89,627 44,250
</TABLE>
- ----------
(1) Includes the financial statement effect of Resources since its August 1997
acquisition, which was accounted for under the purchase method. See Note
1(b) to the Company's Consolidated Financial Statements.
(2) Includes a non-cash, unrealized accounting loss of $764 million and $79
million (after-tax), or $2.69 and $0.31 basic earnings per share, on the
Company's 7% Automatic Common Exchange Securities (ACES) in 1998 and 1997,
respectively. For additional information on the ACES, see Note 1(n) to the
Company's Consolidated Financial Statements.
(3) The 1994 cumulative effect relates to the change in accounting for
postemployment benefits. See also Note 10(e) to the Company's Consolidated
Financial Statements.
(4) All common share data reflect a two-for-one common stock dividend
distribution in December 1995.
(5) The return on average common equity for 1995 includes the gain on the sale
of the Company's cable television subsidiary. The return on average common
equity, excluding the gain, was 11.7%.
(6) The return on average common equity for 1998 includes a non-cash,
unrealized accounting loss of $764 million on the ACES. The return on
average common equity excluding the loss was 12.4%.
(7) Fixed charges exceeds earnings by $181 million in 1998. Excluding the
effect of the non-cash, unrealized accounting loss of $764 million, the
ratio of earnings to fixed charges would have been 2.77.
(8) Includes Cumulative Preferred Stock subject to mandatory redemption and
Company/Resources obligated mandatorily redeemable preferred securities of
subsidiary trusts holding solely junior subordinated debentures of
Company/Resources.
(9) During 1995 and 1996, Electric Operations made payments toward the purchase
of its corporate headquarters building. Such payments were not reflected in
Electric Operations' capital and nuclear fuel expenditures because they
were affiliate transactions eliminated upon consolidation.
26
<PAGE> 31
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS OF THE COMPANY.
The following discussion and analysis should be read in combination with
the consolidated financial statements and notes of Reliant Energy, Incorporated
(Company) contained in Item 8 of this Form 10-K (Company's Consolidated
Financial Statements).
RELIANT ENERGY, INCORPORATED
The Company is a diversified international energy services company. It
operates the nation's tenth largest electric utility in terms of kilowatt-hour
(KWH) sales, and its three natural gas distribution divisions together form the
nation's third largest natural gas distribution operation in terms of customers
served. The Company also invests in international and domestic electric utility
privatizations, gas distribution projects and the development of non-rate
regulated power generation projects. The Company is also a major interstate
natural gas pipeline and energy services company, providing gas transportation,
supply, gathering and storage, and wholesale natural gas and electric power
marketing services.
Effective January 1, 1998, the Company reconfigured its financial reporting
segments to include the following: Electric Operations, Natural Gas
Distribution, Interstate Pipelines, Wholesale Energy Marketing and Generation
(Wholesale Energy), International and Corporate. For segment reporting
information, see Note 15 to the Company's Consolidated Financial Statements.
On August 6, 1997 (Acquisition Date), the Company acquired Reliant Energy
Resources Corp. (formerly, NorAm Energy Corp.) (Resources), a natural gas
gathering, transmission, marketing and distribution company. The acquisition
(Merger) was accounted for as a purchase; accordingly, the Company's results of
operations for 1997 include the results of operations of Resources only for the
period beginning on August 6, 1997 (Acquisition Date).
To enhance comparability between reporting periods, certain information is
presented on a pro forma basis and reflects the acquisition of Resources as if
it had occurred at the beginning of the 1996 and 1997 reporting periods
presented. Pro forma purchase-related adjustments include amortization of
goodwill and the allocation of the fair value of certain assets and liabilities
of Resources. The pro forma results of operations are not necessarily indicative
of the combined results of operations that actually would have occurred had the
acquisition occurred on such dates. The Company believes, however, that the
presentation of pro forma data provides a more meaningful comparative standard
for assessing changes in the Company's financial condition and results of
operations during the years ended December 31, 1997 and 1996, since the pro
forma presentation (i) combines a full year of results of the Company's and
Resources' operations and (ii) gives retroactive effect to purchase - related
adjustments, including the amortization of goodwill and the allocation of the
fair market value of certain Resources assets and liabilities.
All dollar amounts in tables that follow are in millions, except for per
share data, percentages and throughput and other operations data.
27
<PAGE> 32
CONSOLIDATED RESULTS OF OPERATIONS
<TABLE>
<CAPTION>
ACTUAL PRO FORMA
------------------------------ ---------------
TWELVE TWELVE
MONTHS ENDED MONTHS ENDED
DECEMBER 31, DECEMBER 31,
------------------------------ PERCENT --------------- PERCENT
1998 1997 CHANGE 1997 CHANGE
-------------- -------------- ------- --------------- --------
<S> <C> <C> <C> <C> <C>
Revenues..................................... $ 11,488 $ 6,878 67% $ 10,191 13%
Operating Expenses........................... 10,011 5,813 72% 8,976 12%
Operating Income............................. 1,477 1,065 39% 1,215 22%
Other Expenses, Net(1)....................... 1,649 437 277% 546 202%
Income Taxes................................. (30) 206 -- 232 --
Net Income (Loss)(2) ........................ (142) 421 -- 437 --
Basic and Diluted Earnings (Loss) Per
Share..................................... (.50) 1.66 -- 1.55 --
</TABLE>
- ---------
(1) Includes a $1,176 million unrealized accounting loss in 1998 compared to a
$121 million unrealized accounting loss incurred in 1997 relating to the
Company's 7% Automatic Common Exchange Securities (ACES).
See Note 1(n) to the Company's Consolidated Financial Statements.
(2) Includes $37 million of interest income attributable to a tax refund in
1997.
<TABLE>
<CAPTION>
ACTUAL PRO FORMA
--------------------------- --------------------------
TWELVE MONTHS ENDED TWELVE MONTHS ENDED
DECEMBER 31, DECEMBER 31,
--------------------------- PERCENT -------------------------- PERCENT
1997 1996 CHANGE 1997 1996 CHANGE
-------------- ----------- --------- --------------- ---------- -----------
<S> <C> <C> <C> <C> <C> <C>
Revenues............................ $ 6,878 $ 4,095 68% $ 10,191 8,884 15%
Operating Expenses.................. 5,813 3,105 87% 8,976 7,617 18%
Operating Income.................... 1,065 990 8% 1,215 1,267 (4%)
Other Expenses, Net................. 437 385 14% 546 596 (8%)
Income Taxes........................ 206 200 3% 232 245 (5%)
Net Income.......................... 421 405 4% 437 426 3%
Basic and Diluted Earnings Per
Share............................ 1.66 1.66 -- 1.55 1.46 6%
</TABLE>
1998 Compared to 1997 (Actual). The Company reported a consolidated net
loss for 1998 of $142 million ($.50 per share) compared to consolidated net
income of $421 million ($1.66 per share) in 1997. The consolidated net loss
resulted from the accounting treatment of the ACES, which were issued in July
1997. The Company recorded a non-cash, unrealized accounting loss (after-tax) of
$764 million on the ACES in 1998. In 1997, the Company recorded a non-cash,
unrealized accounting loss (after-tax) of $79 million on the ACES, which was
partially offset by $37 million of non-recurring interest income related to a
refund of federal income taxes in 1997. For a discussion of the ACES accounting
loss, see "--Certain Factors Affecting Future Earnings of the Company and its
Subsidiaries - Accounting Treatment of ACES."
After adjusting for non-recurring and other charges (as described above) in
both years, net income for 1998 would have been $622 million ($2.19 per share)
compared to $463 million ($1.83 per share) in 1997. The increase in adjusted net
income for 1998 compared to 1997 was due to improved results from the Company's
Interstate Pipeline, Wholesale Energy and International segments. Net income for
1998 included an $80 million, or $.28 per share, gain on the sale of an
investment in an electric distribution system in Argentina. Also contributing to
the increase were earnings from the businesses acquired in the Merger. These
effects were partially offset by additional depreciation of regulated power
generation assets in compliance with Reliant Energy HL&P's rate of return cap,
as described below, and increased interest expense primarily related to the
Merger.
28
<PAGE> 33
1998 Compared to 1997 (Pro Forma). The Company's reported consolidated net
loss for 1998 was $142 million ($.50 per share) compared to pro forma earnings
of $437 million ($1.55 per share) in 1997.
Excluding the non-recurring and other charges described above, net income
for 1998 would have been $622 million ($2.19 per share) compared to pro forma
net income of $479 million ($1.70 per share) in 1997. The increase in adjusted
net income compared to adjusted pro forma 1997 net income is due primarily to
the same factors discussed above.
1997 Compared to 1996 (Actual). The Company reported consolidated net
income in 1997 of $421 million ($1.66 per share) compared to $405 million ($1.66
per share) in 1996. Although net income increased by $16 million, the Company's
basic and diluted earnings per share remained the same due to the issuance of
approximately 47.8 million additional shares of the Company's common stock in
the Merger. The Company's net income in 1997 reflected the net impact of $42
million from the ACES accounting loss partially offset by non-recurring interest
income. In 1996, the Company recorded non-recurring, after-tax charges of (i)
$62 million for the settlement of South Texas Project Electric Generating
Station (South Texas Project) litigation claims and (ii) $5 million associated
with an investment in two tire-to-energy plants in Illinois.
After adjusting for non-recurring and other charges in both years, net
income for 1997 would have been $463 million ($1.83 per share) compared to $472
million ($1.93 per share) in 1996. The decrease is due in part to the additional
amortization of certain lignite reserves by Electric Operations, the
amortization of goodwill recorded in the Merger and increased interest expense.
The increase in interest on long-term debt and other interest reflect both (i)
the $1.4 billion indebtedness incurred by the Company to fund a portion of the
cost of the Merger and (ii) the consolidation of Resources' existing
indebtedness with that of the Company. Partially offsetting these effects were
increased Electric Operations' sales due to customer growth, improved results at
International and the additional operating income generated by the new business
units acquired in the Merger.
1997 Compared to 1996 (Pro Forma). The Company's pro forma consolidated net
income for 1997 was $437 million ($1.55 per share) compared to $426 million
($1.46 per share) in 1996.
Excluding the non-recurring and other charges described above, the
Company's 1997 pro forma net income would have been $479 million ($1.70 per
share) compared to $493 million ($1.69 per share) in 1996. This decrease in pro
forma earnings, as adjusted for non-recurring and other charges, was principally
the result of (i) hedging-related losses incurred in the first quarter of 1997
by a subsidiary of Resources, which losses were not reflected in the Company's
actual results of operations since they were incurred prior to the Merger,
(ii) a weather-related decline in sales volumes of Natural Gas Distribution and
(iii) increased administrative and general expenses associated with increased
staffing and marketing in connection with increasing the scope of energy
marketing activities.
Pro forma consolidated net income for 1997 and 1996 exceeds actual
consolidated net income for such years because purchase-related costs were more
than offset on a pro forma basis by Resources' earnings for the periods prior to
the Acquisition Date. Such earnings were not part of the reported actual results
of the Company.
RESULTS OF OPERATIONS BY BUSINESS SEGMENT
All business segment data (other than data relating to Electric Operations)
are presented on a pro forma basis for 1997 and 1996 as if the acquisition of
Resources had occurred on January 1 of each year presented.
The following table presents operating income on (i) an actual basis for
the years ended December 31, 1998 and 1997, and (ii) a pro forma basis for each
of the Company's business segments for the years ended December 31, 1997 and
1996.
29
<PAGE> 34
OPERATING INCOME (LOSS) BY BUSINESS SEGMENT
<TABLE>
<CAPTION>
ACTUAL PRO FORMA
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31,
----------------------------- ----------------------------
1998 1997(1) 1997(2) 1996(2)
------------ ------------ ------------ ------------
<S> <C> <C> <C> <C>
Electric Operations.......................... $ 1,014 $ 995 $ 995 $ 997
Natural Gas Distribution..................... 138 55 152 160
Interstate Pipeline.......................... 128 32 99 108
Wholesale Energy............................. 59 1 (15) 22
International................................ 182 20 17 (1)
Corporate.................................... (44) (38) (32) (19)
------------ ------------ ------------ ------------
Total Consolidated........................... $ 1,477 $ 1,065 $ 1,216 $ 1,267
------------ ------------ ------------ ------------
</TABLE>
- ----------
(1) Includes Resources business segments beginning on the Acquisition Date.
(2) Electric Operations operating income data are actual and not pro forma.
ELECTRIC OPERATIONS
Electric Operations' business is conducted under the name "Reliant Energy
HL&P," an unincorporated division of the Company. Electric Operations provides
electric generation, transmission, distribution, and sales to approximately 1.6
million customers in a 5,000 square mile area on the Texas Gulf Coast, including
Houston (the nation's fourth largest city). Electric Operations constitutes the
Company's largest business segment, representing 69% of the Company's
consolidated operating income for 1998.
Electric Operations' earnings are capped at an agreed overall rate of
return formula on a calendar year basis as part of the transition to competition
plan (Transition Plan) approved by the Public Utility Commission of Texas (Texas
Utility Commission) and effective January 1, 1998. As a result of this plan, any
earnings in 1998 or 1999 above the maximum allowed return cap of 9.844% on
invested capital will be offset by additional depreciation of Electric
Operations' generation assets. The Transition Plan also approved the
implementation of base rate credits to residential customers of 4% in 1998 and
an additional 2% in 1999. Commercial customers whose monthly billing is 1000 kva
or less receive base rate credits of 2% in 1998 and 1999. For more information
regarding the Transition Plan, including a pending judicial review of portions
of the Transition Plan, see Note 3(b) to the Company's Consolidated Financial
Statements.
The following table provides summary data, before taxes, regarding the
actual results of operations of Electric Operations for 1998, 1997 and 1996.
<TABLE>
<CAPTION>
YEAR ENDED
DECEMBER 31,
----------------------- PERCENT
1998 1997 CHANGE
----------- ----------- ------------
<S> <C> <C> <C>
Operating Revenues:
Base Revenues(1)....................................................... $ 2,969 $ 2,839 5%
Reconcilable Fuel Revenues(2).......................................... 1,381 1,413 (2%)
---------- ----------
Total Operating Revenues............................................. 4,350 4,252 2%
---------- ----------
Operating Expenses:
Fuel Expense........................................................... 1,064 1,091 (2%)
Purchased Power........................................................ 391 386 1%
Operation Expense...................................................... 635 641 (1%)
Maintenance Expense.................................................... 234 228 3%
Depreciation and Amortization Expense.................................. 650 569 14%
Other Operating Expenses............................................... 362 342 6%
---------- ----------
Total Operating Expenses............................................. 3,336 3,257 2%
---------- ----------
Operating Income.......................................................... $ 1,014 $ 995 2%
========== ==========
</TABLE>
30
<PAGE> 35
<TABLE>
<CAPTION>
YEAR ENDED
DECEMBER 31,
----------------------- PERCENT
1998 1997 CHANGE
----------- ----------- ------------
<S> <C> <C> <C>
Operating Revenues:
Base Revenues(1)...........................................................$ 2,839 $ 2,743 3%
Reconcilable Fuel Revenues(2).............................................. 1,413 1,282 10%
---------- ----------
Total Operating Revenues................................................. 4,252 4,025 6%
---------- ----------
Operating Expense:
Fuel Expense............................................................... 1,091 1,025 6%
Purchased Power............................................................ 386 322 20%
Operation Expense.......................................................... 641 543 18%
Maintenance Expense........................................................ 228 249 (8%)
Depreciation and Amortization Expense...................................... 569 546 4%
Other Operating Expenses................................................... 342 343 --
---------- ----------
Total Operating Expenses................................................. 3,257 3,028 8%
---------- ----------
Operating Income..............................................................$ 995 $ 997 --
---------- ----------
</TABLE>
- ----------
(1) Includes miscellaneous revenues, certain non-reconcilable fuel revenues and
certain purchased power-related revenues.
(2) Includes revenues collected through a fixed fuel factor and surcharges net
of adjustments for over/under recovery. See -- Operating Revenues --
Electric Operations."
OPERATING INCOME -- ELECTRIC OPERATIONS
1998 Compared to 1997. Electric Operations' operating income (before income
taxes) was $1,014 million compared with $995 million the previous year. The
increase of $19 million in operating income was due to higher revenues from the
unusually hot weather in 1998 and customer growth, reduced by base rate credits
provided under the Transition Plan. Under the Transition Plan, the Company
recorded additional depreciation on Electric Operation's generation assets,
which resulted in depreciation and amortization expense increasing by $82
million between 1997 and 1998. Total KWH sales rose 8% during 1998, with
increases of 9% in residential sales, 6% in commercial sales and 3% in firm
industrial sales.
1997 Compared to 1996. Electric Operations' operating income (before income
taxes) was $995 million in 1997 compared with $997 million in 1996. The decrease
in operating income was due to increases in operations expense and depreciation
and amortization expense in 1997, partially offset by increased revenues from
electric sales growth and decreases in maintenance expense, as described below.
Total KWH sales rose 3% during 1997, with increases of 1% in residential sales,
6% in commercial sales and 2% in firm industrial sales.
OPERATING REVENUES -- ELECTRIC OPERATIONS
1998 Compared to 1997. Electric Operations' $130 million increase in 1998
base revenues is primarily the result of unusually hot weather and the impact of
customer growth, net of base rate credits implemented under the Transition Plan.
In 1998, Electric Operations implemented a base rate discount of $74 million. In
addition, growth in usage and number of customers contributed an additional $48
million in base revenues in 1998.
Electric Operations' 2% decrease in reconcilable fuel revenue in 1998
resulted primarily from decreased natural gas prices. The decrease in natural
gas prices, however, was largely offset by increased KWH sales resulting from
hotter weather. The Texas Utility Commission provides for recovery of certain
fuel and purchased power costs through a fixed fuel factor included in electric
rates. The fixed fuel factor is established during either a utility's general
rate proceeding or its fuel factor proceeding and is generally effective for a
minimum of six months. Revenues collected through such factor are adjusted
monthly to equal expenses; therefore, such revenues and expenses have no effect
on earnings unless fuel costs are determined not to be recoverable. The adjusted
over/under recovery of fuel costs is recorded on the
31
<PAGE> 36
Company's Consolidated Balance Sheets as fuel-related credits or fuel-related
debits, respectively. Fuel costs are reviewed during periodic fuel
reconciliation proceedings, which are required at least every three years.
Electric Operations filed a fuel reconciliation proceeding with the Texas
Utility Commission on January 30, 1998 covering $3.5 billion of fuel costs for
the three year period ending July 31, 1997. In December 1998, the Texas Utility
Commission issued a final order that allowed Electric Operations to recover
eligible fuel costs for the three-year period ending July 31, 1997, with some
exceptions. Under the order, the Company reclassified $40 million in costs
associated with certain fuel-related capital improvement projects from eligible
fuel expense to invested capital. The order also required an additional
reduction of $12 million in eligible fuel expense relating to the three-year
period ending July 31, 1997.
In April 1998, Electric Operations filed a petition to revise the fixed
fuel factor and implement a surcharge for under-collected fuel costs. The Texas
Utility Commission approved implementation of the revised overall fixed fuel
factor and a temporary fuel surcharge in the amount of $125 million (inclusive
of the previously existing fuel surcharge balance) to be collected over a 12 to
18 month period. The approved fuel factor and surcharge were implemented for
customer billings beginning July 1, 1998. As of December 31, 1998 and 1997,
Electric Operations' cumulative under-recovery of fuel costs was $45 million and
$172 million including interest, respectively.
1997 Compared to 1996. Electric Operations' 3% increase in base revenue in
1997 compared to 1996 was primarily the result of newly recorded transmission
revenues. Electric Operations' transmission revenues (which are considered
miscellaneous revenues) in 1997 were $86 million but were offset by transmission
expenses of $88 million. For information regarding these transmission revenues,
see "-- Certain Factors Affecting Future Earnings of the Company and its
Subsidiaries -- Competition and Restructuring of Electric Utility Industry"
below. Electric Operations' 10% increase in reconcilable fuel revenue in 1997
resulted primarily from increased natural gas prices in that year.
In 1997, Electric Operations implemented (i) a $70 million temporary fuel
surcharge (inclusive of interest) effective for the first six months of 1997 and
(ii) a $62 million temporary fuel surcharge (inclusive of interest) effective
for the last six months of 1997. In December 1997, the Texas Utility Commission
approved the implementation of a $102 million (inclusive of interest) temporary
fuel surcharge which was implemented by Electric Operations on January 1, 1998
with recovery extending from 8 months to 16 months depending on the customer
class. Electric Operations requested the surcharge in order to recover its
under-recovery of fuel expenses for the period March 1997 through August 1997.
This under-recovery was included in the surcharge that began July 1, 1998.
FUEL AND PURCHASED POWER EXPENSE -- ELECTRIC OPERATIONS
Fuel costs constitute the single largest expense for Electric Operations.
The mix of fuel sources for generation of electricity is determined primarily by
system load and the unit cost of fuel consumed. The average cost of fuel used by
Electric Operations in 1998 was $1.70 per million British Thermal Units (MMBtu)
($2.18 for natural gas, $1.78 for coal, $1.19 for lignite, and $.48 for
nuclear). In 1997, the average cost of fuel was $1.87 per MMBtu ($2.60 for
natural gas, $2.02 for coal, $1.08 for lignite, and $0.54 for nuclear). Fuel
costs are reconciled to fuel revenues resulting in no effect on earnings unless
fuel costs are determined not to be recoverable.
1998 Compared to 1997. Fuel expenses in 1998 decreased by $27 million or 2%
below 1997 expenses. The decrease was driven by a significant decrease in the
average unit cost of natural gas, which declined from $2.60 per MMBtu in 1997 to
$2.18 per MMBtu in 1998. Purchased power expenses increased in 1998 by $5
million or 1% over 1997 expenses. This increase was a result of additional
purchases through the Electric Reliability Council of Texas (ERCOT) of $18
million offset by a reduction in purchases from cogenerators of $13 million.
Additionally, 1998 fuel expense includes a $12 million charge to non-recoverable
fuel in accordance with the Fuel Reconciliation Proceeding discussed above.
32
<PAGE> 37
1997 Compared to 1996. Fuel expenses in 1997 increased by $66 million or 6%
over 1996 expenses. The increase was driven by significant increases in the
average unit cost of natural gas, which rose to $2.60 per MMBtu in 1997 from
$2.31 per MMBtu in 1996. Purchased power expenses increased in 1997 by $63
million or 20% over 1996 expenses. This change was driven primarily due to
higher prices paid to qualifying facilities for purchased electric energy
principally as a result of increases in natural gas prices, energy purchased
under Electric Operations' joint dispatching agreement with the city of San
Antonio (see Note 12(c) to the Company's Consolidated Financial Statements) and
Electric Operations' participation in the newly deregulated Texas wholesale
energy market in order to buy and sell energy to provide lower costs to its
customers.
OPERATION AND MAINTENANCE EXPENSES, DEPRECIATION, AMORTIZATION AND OTHER --
ELECTRIC OPERATIONS
In order to reduce Electric Operations' exposure to potentially stranded
costs related to generating assets, the Transition Plan permits the redirection
of depreciation expense to generation assets from transmission, distribution and
general plant assets. In addition, the Transition Plan provides that all
earnings above a 9.844% overall annual rate of return on invested capital be
used to recover Electric Operations' investment in generation assets. As a
result, Electric Operations recorded $194 million in additional depreciation and
redirected $195 million in existing depreciation expense to generation assets in
1998.
1998 Compared to 1997. Operation, maintenance and other operating expenses
increased $20 million in 1998, including $9 million due to transmission tariffs
within ERCOT. These transmission expenses were largely offset by $7 million in
transmission tariff revenue. Franchise fees paid to cities increased $11 million
due to increased sales in 1998.
In 1998, the Company recorded additional depreciation expense for Electric
Operations of $194 million, which is $144 million more than recorded during the
same period last year, as provided by the Transition Plan. The comparative
increase was less than it otherwise would have been because amortization of the
investment in lignite reserves associated with a canceled generation project was
$62 million lower in 1998 than in 1997. In 1996, Electric Operations began
amortizing its $153 million investment in these lignite reserves. The lignite
reserves will be fully amortized no later than 2002.
1997 Compared to 1996. Operations and maintenance expense increased $76
million in 1997. The increase included $88 million due to transmission tariff
expenses within ERCOT, offset by $86 million of transmission tariff revenue.
In 1997, Electric Operations incurred $17 million in work force severance
expenses compared to $30 million of such expenses in 1996.
Depreciation and amortization expense increased $23 million in 1997
compared to 1996. The increase is due to the additional amortization of $16
million of Electric Operations' investment in lignite reserves. In 1997 and
1996, Electric Operations wrote down its investment in the South Texas Project
by $50 million in addition to ordinary depreciation associated with the South
Texas Project. The additional amortization of the lignite reserves and the
depreciation of the South Texas Project were permitted under Electric
Operations' rate order in Docket 12065. For additional information regarding
these amortizations, see Note 1(f) to the Company's Consolidated Financial
Statements.
NATURAL GAS DISTRIBUTION
Natural Gas Distribution operations are conducted through three
unincorporated divisions of Resources (Reliant Energy Arkla, Reliant Energy
Entex and Reliant Energy Minnegasco) and are included in the Company's actual
consolidated results of operations beginning on the Acquisition Date. These
operations consist of natural gas sales to, and natural gas transportation for,
residential, commercial and industrial customers in six states:
Arkansas, Louisiana, Minnesota, Mississippi, Oklahoma and Texas.
33
<PAGE> 38
The following tables provide summary data regarding the actual results of
operations of Natural Gas Distribution for 1998 and unaudited pro forma
financial results of operations for 1997 and 1996.
<TABLE>
<CAPTION>
ACTUAL PRO FORMA
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31, PERCENT
1998 1997 CHANGE
-------------- -------------- --------------
<S> <C> <C> <C>
Operating Revenues:
Base Revenues................................................... $ 779 $ 814 (4%)
Recovered Gas Revenues.......................................... 1,034 1,388 (26%)
---------- ----------
Total Operating Revenues...................................... 1,813 2,202 (18%)
---------- ----------
Operating Expenses:
Natural Gas..................................................... 1,085 1,440 (25%)
Operation and Maintenance....................................... 368 384 (4%)
Depreciation and Amortization................................... 130 124 5%
Other Operating Expenses........................................ 92 102 (10%)
---------- ----------
Total Operating Expenses...................................... 1,675 2,050 (18%)
---------- ----------
Operating Income................................................... $ 138 $ 152 (9%)
========== ==========
Throughput Data (in billion cubic feet (BCF)):
Residential and Commercial Sales................................ 286 326 (12%)
Industrial Sales................................................ 56 59 (5%)
Transportation.................................................. 44 42 5%
---------- ----------
Total Throughput.............................................. 386 427 (10%)
========== ==========
PRO FORMA YEAR ENDED
DECEMBER 31,
------------------------ PERCENT
1997 1996 CHANGE
-------- -------- -------
Operating Revenues:
Base Revenues................................................... $ 814 $ 764 7%
Recovered Gas Revenues.......................................... 1,388 1,349 3%
-------- --------
Total Operating Revenues...................................... 2,202 2,113 4%
-------- --------
Operating Expenses:
Natural Gas..................................................... 1,440 1,348 7%
Operation and Maintenance....................................... 384 381 1%
Depreciation and Amortization................................... 124 121 2%
Other Operating Expenses(1)..................................... 102 103 (1%)
-------- --------
Total Operating Expenses...................................... 2,050 1,953 5%
-------- --------
Operating Income................................................... $ 152 $ 160 (5%)
======== ========
Throughput Data (in BCF):
Residential and Commercial Sales................................ 326 333 (2%)
Industrial Sales................................................ 59 58 2%
Transportation.................................................. 42 42 --
-------- --------
Total Throughput.............................................. 427 433 (1%)
======== ========
</TABLE>
- ----------
(1) Before a $6 million one-time charge incurred in 1996 for early retirement
and severance costs.
1998 (Actual) Compared to 1997 (Pro Forma). Operating income was $138
million in 1998 compared to pro forma operating income of $152 million in 1997.
The $14 million decrease reflects the lower demand for natural gas heating that
resulted from milder weather in 1998. The negative impact of weather was
partially offset by (i) the favorable impact of purchased gas adjustments during
this period on Reliant Energy Arkla's operating income, (ii) lower operating
expenses and (iii) increased revenue resulting from Reliant Energy Minnegasco's
performance based rate plan.
34
<PAGE> 39
The $389 million decrease in 1998 actual operating revenues compared to
1997 pro forma operating revenues is primarily attributable to a decrease in the
price of purchased gas and decreased sales volume primarily due to milder
weather in 1998.
1997 Compared to 1996 (Pro Forma). Pro forma operating income was $152
million in 1997 compared to $160 million (before a one-time charge of $6 million
for early retirement and severance) in 1996. The decrease of approximately $8
million in 1997 pro forma operating income is principally due to decreased
Reliant Energy Minnegasco customer usage because of warmer weather and customer
conservation, decreased Reliant Energy Arkla customer usage because of warmer
weather (primarily in the first quarter of 1997) and the unfavorable impact in
1997 of a purchased gas adjustment mechanism on Reliant Energy Arkla. Partially
offsetting the decrease was an increase in Reliant Energy Minnegasco's
performance based rate incentive recoveries and customer growth and increased
revenues from Reliant Energy Entex due to rate relief granted in 1996 and fully
reflected in 1997.
The increase of approximately $89 million in pro forma Natural Gas
Distribution operating revenue for the year ended December 31, 1997 in
comparison to the corresponding period of 1996 is principally due to the
increase in the market price of gas.
The $92 million increase in purchased gas costs in 1997 compared to 1996
primarily reflects the increase in Natural Gas Distribution's average cost of
gas in 1997 (consistent with the overall increase in the market price of gas
during such period) along with the purchased gas adjustment referenced above.
INTERSTATE PIPELINES
Interstate Pipelines' operations are conducted through Reliant Energy Gas
Transmission Company (REGT) and Mississippi River Transmission Corporation
(MRT), two wholly owned subsidiaries of Resources.
The following table provides summary data regarding the actual results of
operations of Interstate Pipelines for 1998 and pro forma results of operations
for 1997 and 1996.
<TABLE>
<CAPTION>
ACTUAL PRO FORMA
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31, PERCENT
1998 1997 CHANGE
--------------- ---------------
<S> <C> <C> <C>
Operating Revenues................................................. $ 282 $ 295 (4%)
Operating Expenses:
Natural Gas..................................................... 27 45 (40%)
Operation and Maintenance....................................... 69 88 (22%)
Depreciation and Amortization................................... 44 48 (8%)
Other Operating Expenses........................................ 14 15 (7%)
---------- ----------
Total Operating Expenses...................................... 154 196 (21%)
---------- ----------
Operating Income................................................... $ 128 $ 99 29%
========== ==========
Throughput Data (in MMBtu):
Natural Gas Sales.................................................. 16 18 (11%)
Transportation..................................................... 825 911 (9%)
Elimination(1).................................................. (15) (17) 12%
---------- ----------
Total Throughput................................................... 826 912 (9%)
========== ==========
</TABLE>
35
<PAGE> 40
<TABLE>
<CAPTION>
PRO FORMA YEAR ENDED PERCENT
DECEMBER 31, CHANGE
-------------------------------
1997 1996
--------------- ---------------
<S> <C> <C> <C>
Operating Revenues................................................. $ 295 $ 347 (15%)
Operating Expenses:
Natural Gas..................................................... 45 76 (41%)
Operation and Maintenance....................................... 88 82 7%
Depreciation and Amortization................................... 48 50 (4%)
Other Operating Expenses(1)..................................... 15 31 (52%)
---------- ----------
Total Operating Expenses...................................... 196 239 (18%)
---------- ----------
Operating Income................................................... $ 99 $ 108 (8%)
========== ==========
Throughput Data (in MMBtu):
Natural Gas Sales.................................................. 18 33 (45%)
Transportation..................................................... 911 952 (4%)
Elimination(1)................................................. (17) (31) 45%
---------- ----------
Total Throughput................................................... 912 954 (4%)
========== ==========
</TABLE>
- --------
(1) Elimination of volumes both transported and sold.
1998 (Actual) Compared to 1997 (Pro Forma). Interstate Pipelines' operating
income for 1998 was $128 million compared to $99 million for 1997 on a pro forma
basis. The increase in operating income for 1998 is primarily due to $11 million
of pre-tax, non-recurring items recorded in 1998 for favorable litigation and
rate case settlements. The increase in operating income also reflects improved
operating margins and reductions in operating expenses. The increase in
operating income for 1998 was partially offset by $7 million of non-recurring
transportation revenues recorded in the first quarter of 1997, as discussed
below.
Operating revenues for Interstate Pipelines decreased by $13 million in
1998 compared to pro forma 1997 revenues. The decrease in revenues is due in
part to $7 million of non-recurring transportation revenues recognized in the
first quarter of 1997. These revenues were recognized following a settlement
with Reliant Energy Arkla related to transportation service. The settlement with
Reliant Energy Arkla resulted in reduced transportation rates which also reduced
revenues for 1998. Lower spot prices in the fourth quarter of 1998 and reduced
sales volumes also contributed to the reduction in operating revenues. These
decreases were partially offset by the settlement of outstanding gas purchase
contract litigation, which resulted in the recognition of approximately $6
million of revenues in the second quarter of 1998. The 4% decline in total
throughput reflected the impact of unseasonably warm winter weather.
Interstate Pipelines' 1998 operating expense declined $42 million in
comparison to 1997 pro forma operating expense. Contributing to the decrease
were the MRT rate settlement in the first quarter of 1998, which provided for a
retroactive reduction of MRT's depreciation rates, the impact of continued cost
control initiatives and reduced pension and benefit expenses.
Natural gas expense decreased $18 million in 1998 compared to pro forma
natural gas expense in 1997 primarily due to lower gas sales volumes and lower
prices for purchased gas.
Operation and maintenance expense decreased $19 million in 1998 in
comparison to pro forma operation and maintenance expense for 1997. The decrease
was primarily due to the impact of cost control initiatives and decreased
maintenance due to milder weather in the first quarter of 1998.
Depreciation expense decreased $4 million in 1998, compared to pro forma
depreciation expense in 1997 primarily due to a rate settlement recorded in the
first quarter of 1998. The rate settlement, effective January 1998, provided for
a $5 million reduction of MRT's depreciation rates retroactive to July 1996.
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<PAGE> 41
During 1998, Interstate Pipelines' largest unaffiliated customer was a
natural gas utility that serves the greater St. Louis metropolitan area.
Revenues from this customer are generated pursuant to several long-term firm
transportation and storage contracts that currently are scheduled to expire at
various dates between October 1999 and May 2000. Interstate Pipeline is
currently negotiating with the natural gas utility to renew these agreements. If
such contracts are not renewed, the results of operations of Interstate
Pipelines will be adversely affected.
1997 Compared to 1996 (Pro Forma). Pro forma operating income was $99
million in 1997 compared to $108 million (before a one-time charge of $17
million for early retirement and severance) in 1996. This decrease of
approximately $9 million in Interstate Pipelines' pro forma operating income
between 1997 and 1996 results primarily from three factors: (i) a 6% decrease in
transportation revenues, (ii) a 43% decrease in natural gas sales revenue (as
described below) and (iii) lower demand for natural gas transportation as a
result of lower natural gas consumption (primarily weather-related) in the
eastern markets served by the segment. These factors were offset partially by an
approximately 18% decline in operating expenses primarily due to decreases in
gas purchased.
Pro forma operating revenues for Interstate Pipelines decreased by $52
million (15%) for the year ended December 31, 1997 in comparison to the
corresponding period of 1996. The decrease in revenues primarily reflects a
decline in natural gas sales revenue resulting from the expiration in 1996 of an
unbundled natural gas sales contract between Interstate Pipelines and Reliant
Energy Arkla. Natural gas sales to Natural Gas Distribution were $60 million in
1996 and none in 1997.
The decline in transportation revenues is largely attributable to price
differentials between the average spot price for Mid-continent natural gas
(Interstate Pipelines' primary supply area) and Gulf Coast natural gas in 1997.
The $31 million decrease in gas purchased costs in 1997 compared to 1996 is
largely attributable to the expiration of long-term supply contracts entered
into prior to unbundling, as discussed above. Other operating expenses decreased
in 1997 compared to 1996 primarily due to the elimination of non-recurring costs
combined with cost reductions related to the 1996 early retirement and severance
program and reductions in costs allocated from Resources.
WHOLESALE ENERGY
Wholesale Energy includes the acquisition, development and operation of,
and sales of capacity and energy from, non-utility power generation facilities;
the operations of the Company's wholesale energy trading and marketing business;
and natural gas gathering activities.
Reliant Energy Power Generation, Inc. (Power Generation) was formed in
March 1997 to pursue the acquisition of electric generation assets as well as
the development of new non-rate regulated power generation facilities. Since
March 1997, the Company has invested approximately $348 million in Power
Generation acquisitions and development projects. Power Generation currently has
entered into commitments associated with various generation projects amounting
to $252 million. The Company expects that Power Generation will actively pursue
the acquisition of additional generation assets and the development of
additional new non-rate regulated generation projects. Depending on the timing
and success of Power Generation's future efforts, the Company believes that
resulting expenditures could be substantial. During 1997, Power Generation's
results were included in the Corporate segment. Segment information for 1997 for
Wholesale Energy has been revised to reflect the inclusion of Power Generation
and the exclusion of Reliant Energy Retail, Inc., which is now reported as part
of the Corporate segment.
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<PAGE> 42
To minimize the Company's risks associated with fluctuations in the price
of natural gas and transportation, the Company, primarily through Reliant Energy
Services, Inc. (Reliant Energy Services), a wholly owned subsidiary of
Resources, enters into futures transactions, swaps and options in order to hedge
against market price changes affecting (i) certain commitments to buy, sell and
transport natural gas, (ii) existing natural gas storage and heating oil
inventory, (iii) future power sales by and natural gas purchase by generation
facilities, (iv) crude oil and refined products and (v) certain anticipated
transactions, some of which carry off-balance sheet risk. Reliant Energy
Services also enters into commodity derivatives in its trading and price risk
management activities. For a discussion of the Company's accounting treatment of
derivative instruments, see Note 2 to the Company's Consolidated Financial
Statements and "Quantitative and Qualitative Disclosures About Market Risk" in
Item 7A of this Form 10-K.
The Company believes that Reliant Energy Services' energy trading,
marketing, and risk management activities complement Power Generation's strategy
of developing and/or acquiring unregulated generation assets in key markets.
Reliant Energy Services supplies fuel to Power Generation's existing generation
assets and sells electricity produced by these assets. As a result, the Company
has made, and expects to continue to make, significant investments in developing
Reliant Energy Services' internal software, trading and personnel resources.
The following table provides summary data regarding the actual results of
operations of Wholesale Energy for 1998 and pro forma results of operations of
Wholesale Energy for 1997 and 1996.
<TABLE>
<CAPTION>
ACTUAL PRO FORMA
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31, PERCENT
1998 1997 CHANGE
--------------- ---------------
<S> <C> <C> <C>
Operating Revenues................................................. $ 4,456 $ 3,042 46%
Operating Expenses:
Natural Gas..................................................... 2,367 2,618 (10%)
Purchased Power................................................. 1,829 313 484%
Operation and Maintenance....................................... 178 117 52%
Depreciation and Amortization................................... 18 7 157%
Other Operating Expenses........................................ 5 2 150%
----------- ----------
Total Operating Expenses.................................... 4,397 3,057 44%
----------- ----------
Operating Income................................................... $ 59 $ (15) --
=========== ==========
Operations Data:
Natural Gas (in BCF):
Sales......................................................... 1,168 958 22%
Gathering..................................................... 237 242 (2%)
----------- ----------
Total....................................................... 1,405 1,200 17%
=========== ==========
Electricity (in thousand MWH):
Wholesale Power Sales......................................... 65,228 24,997 161%
=========== ==========
</TABLE>
38
<PAGE> 43
<TABLE>
<CAPTION>
PRO FORMA YEAR ENDED PERCENT
DECEMBER 31, CHANGE
-------------------------------
1997 1996
--------------- ---------------
<S> <C> <C> <C>
Operating Revenues................................................. $ 3,042 $ 2,146 42%
Operating Expenses:
Natural Gas..................................................... 2,618 1,967 33%
Purchased Power................................................. 313 63 397%
Operation and Maintenance....................................... 117 87 34%
Depreciation and Amortization................................... 7 6 17%
Other Operating Expenses........................................ 2 1 100%
----------- ----------
Total Operating Expenses.................................... 3,057 2,124 44%
----------- ----------
Operating Income (Loss)............................................ $ (15) $ 22 (168%)
=========== ==========
Operations Data:
Natural Gas (in BCF):
Sales......................................................... 958 877 9%
Gathering..................................................... 242 231 5%
----------- ----------
Total....................................................... 1,200 1,108 8%
=========== ==========
Electricity (in thousand MWH):
Wholesale Power Sales......................................... 24,997 2,776 800%
=========== ==========
</TABLE>
1998 (Actual) Compared to 1997 (Pro Forma). Wholesale Energy reported
operating income of $59 million compared to a pro forma loss of $15 million in
1997. The increase was primarily due to operating results from Power
Generation's investment in non-regulated generating assets and related trading
and marketing activities. Capitalization of previously expensed development
costs related to successful project starts in Nevada, California and Texas also
contributed to the increase. These improved results were partially offset by
increased operating expenses at Reliant Energy Services, as discussed below. In
1997, operating income was negatively affected by hedging losses at Reliant
Energy Services associated with sales under peaking contracts and losses from
the sale of natural gas held in storage and unhedged in the first quarter of
1997 totaling $17 million.
Operating revenues for Wholesale Energy increased $1.4 billion (46%) in
comparison to pro forma 1997 operating revenues due almost entirely to an
increase in wholesale power sales by Power Generation and Reliant Energy
Services. The benefit of the increase in natural gas sales volume was primarily
offset by lower gas sales prices.
Operating expense increased $1.3 billion compared to pro forma operating
expense for 1997 primarily due to $1.5 billion in increased power costs related
to energy trading and marketing activities. Natural gas expenses decreased $251
million (10%) compared to pro forma 1997 due to the reduction in the price of
natural gas in 1998. Operation and maintenance expense increased $61 million
(52%) in 1998 primarily due to power plant acquisitions in California and costs
associated with staffing increases at Reliant Energy Services to support
increased sales and marketing efforts and an increase in a credit reserve due to
increased counterparty credit and performance risk associated with higher prices
and higher volatility in the electric power market recorded in the second
quarter of 1998.
1997 Compared to 1996 (Pro Forma). The pro forma operating loss for 1997
was $15 million compared to operating income of $22 million in 1996. This
decrease of approximately $37 million (168%) was primarily attributed to: (i)
hedging losses associated with anticipated first quarter 1997 sales under
peaking contracts and (ii) losses from the sale of natural gas held in storage
and unhedged in the first quarter of 1997 totaling $17 million. In addition,
operating expenses increased $11 million largely due to increased staffing and
marketing activities made in support of the increased sales and expanded
marketing efforts. Partially offsetting these unfavorable impacts were increased
margins from natural gas gathering activities.
Pro forma operating revenues for Wholesale Energy increased by $896 million
(42%) for 1997 in comparison to 1996 due to increased natural gas and
electricity trading volumes. Increased volumes in 1997 had minimal effect on
operating income due to low operating margins in both periods.
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<PAGE> 44
Natural gas and purchased power expense increased $901 million (44%) in
1997 compared to 1996 primarily due to increased gas and electricity marketing
activities net of hedging losses and losses from the sale of natural gas, as
discussed above.
INTERNATIONAL
International includes the results of operations of Reliant Energy
International, Inc. (Reliant Energy International) and the international
operations of Resources (Resources International). Reliant Energy International
is a wholly owned subsidiary of the Company that participates in the development
and acquisition of foreign independent power projects and the privatization of
foreign generation and distribution facilities. Substantially all of Reliant
Energy International's operations to date have been in Central and South
America.
International intends to evaluate and consider a wide array of potential
business strategies, including possible acquisitions, restructurings,
reorganizations and/or dispositions of currently owned properties or
investments. The Company believes pursuit of any of the above strategies, or any
combination thereof could have a significant impact on the business, operations
and financial condition of International or the Company.
For information regarding foreign currency matters, including the impact of
the devaluation of the Brazilian real in the first quarter of 1999, see Note 16
to the Company's Consolidated Financial Statements and "-- Certain Factors
Affecting Future Earnings of the Company and its Subsidiaries -- Risks of
International Operations" and "Quantitative and Qualitative Disclosures about
Market Risk" in Item 7A of this Form 10-K. For additional information about the
accounting treatment of certain of International's foreign investments, see Note
5 to the Company's Consolidated Financial Statements.
Results of operations data for International are presented in the following
table on an actual basis for 1998 and on a pro forma basis as if the acquisition
of Resources had occurred as of January 1, 1997 and 1996, as applicable. The
primary pro forma adjustment made to this segment in connection with the
acquisition is to give effect to the development costs and other expenditures
incurred by Resources International prior to the Acquisition Date. The
adjustment had no effect on operating revenues.
<TABLE>
<CAPTION>
PRO FORMA
ACTUAL PRO FORMA YEAR ENDED
YEAR ENDED YEAR ENDED PERCENT --------------------------- PERCENT
1998 1997 CHANGE 1997 1996 CHANGE
------------- ------------- ----------- ------------- ------------- -------------
<S> <C> <C> <C> <C> <C> <C>
Operating Revenues............... $ 259 $ 92 182% $ 92 $ 62 48%
Operating Expenses:
Fuel........................... 20 21 (5%) 21 19 11%
Operation and Maintenance...... 53 50 6% 50 42 19%
Depreciation and amortization.. 4 4 4 2 100%
---------- ---------- ---------- --------
Total Operating Expenses... 77 75 3% 75 63 19%
---------- ---------- ---------- --------
Operating Income (Loss).......... $ 182 $ 17 $ 17 $ (1)
========== ========== ========== ========
</TABLE>
1998 (Actual) Compared to 1997 (Pro Forma). International had operating
income of $182 million compared to pro forma operating income of $17 million in
1997. The increase in operating income is primarily due to a $138 million pretax
gain on the sale of Reliant Energy International's 63% interest in an Argentine
electric distribution company. Equity earnings from Reliant Energy
International's 1998 acquisitions of equity interests in utility systems in El
Salvador and Colombia also contributed to the increase in operating income.
1997 Compared to 1996 (Pro Forma). Pro forma operating income for 1997 was
$17 million compared to an operating loss of $1 million for 1996. 1996 includes
an $8 million pre-tax non-recurring charge related to the write-off of a portion
of Reliant Energy International's investment in two tire-to-energy plants.
Excluding non-recurring charges, International would have had operating income
in 1996 of $7 million. The remaining increase in 1997 operating income is due to
increased equity earnings of $32 million partially offset by higher operation
expenses resulting from increased
40
<PAGE> 45
corporate and project development costs. Equity earnings increased primarily
due to investments in Brazil and Colombia. Light Servicos de Eletricidade S.A.
(Light) reported enhanced results and a full year of operations in 1997 compared
to only seven months in 1996. Reliant Energy International's June 1997
investment in a 28.35% indirect interest in Empresa de Energia del Pacifico
S.A.E.S.P (EPSA), a Colombian electric utility also contributed to the increase
in equity income.
CORPORATE
Corporate. Corporate includes the operations of certain non-rate regulated
retail services businesses, certain real estate holdings of the Company,
unallocated corporate costs and inter-unit eliminations.
Corporate had an operating loss of $44 million for 1998 compared to a pro
forma operating loss of $32 million for 1997. The increased loss was primarily
due to expensed development costs, increased expenses associated with
information system costs and increased liabilities associated with certain
compensation plans.
In 1997, Corporate's pro forma operating loss was $32 million compared to a
pro forma operating loss of $19 million in 1996. The increase in pro forma
operating loss was primarily due to losses from the Company's non-regulated
utility service businesses, consumer services and non-regulated retail electric
services businesses.
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<PAGE> 46
CERTAIN FACTORS AFFECTING FUTURE EARNINGS
OF THE COMPANY AND ITS SUBSIDIARIES
Earnings for the past three years are not necessarily indicative of future
earnings and results. The level of future earnings depends on numerous factors
including (i) the future growth in the Company's and its subsidiaries' energy
sales; (ii) weather; (iii) the success of the Company's and its subsidiaries'
entry into non-rate regulated businesses such as energy marketing and
international and domestic power projects; (iv) the Company's and its
subsidiaries' ability to respond to rapid changes in a competitive environment
and in the legislative and regulatory framework under which they have
traditionally operated; (v) rates of economic growth in the Company's and its
subsidiaries' service areas; (vi) the ability of the Company and its
subsidiaries to control costs and to maintain pricing structures that are both
attractive to customers and profitable; (vii) the outcome of future rate
proceedings; (viii) the effect that foreign exchange rate changes may have on
the Company's investments in international operations; and (ix) future
legislative initiatives.
In order to adapt to the increasingly competitive environment in which the
Company operates, the Company continues to evaluate a wide array of potential
business strategies, including business combinations or acquisitions involving
other utility or non-utility businesses or properties, internal restructuring,
reorganizations or dispositions of currently owned properties or currently
operating business units and new products, services and customer strategies. In
addition, the Company continues to engage in new business ventures, such as
electric power trading and marketing, which arise from competitive and
regulatory changes in the utility industry.
COMPETITION AND RESTRUCTURING OF THE ELECTRIC UTILITY INDUSTRY
The electric utility industry is becoming increasingly competitive due to
changing government regulations, technological developments and the availability
of alternative energy sources.
Long-Term Trends in Electric Utility Industry. The electric utility
industry historically has been composed of vertically integrated companies
providing electric service on an exclusive basis within governmentally-defined
geographic areas. Prices for electric service have typically been set by
governmental authorities under principles designed to provide the utility with
an opportunity to recover its cost of providing electric service plus a
reasonable return on its invested capital. Federal legislation and regulation as
well as legislative and regulatory initiatives in various states have encouraged
competition among electric utility and non-utility owned power generators. These
developments, combined with increased demand for lower-priced electricity and
technological advances in electric generation, have continued to move the
electric utility industry in the direction of more competition.
Based on a strategic review of the Company's business and of ongoing
developments in the electric utility and related industries regarding
competition, regulation and consolidation, the Company's management believes
that the electric utility industry will continue its path toward competition,
albeit on a state-by-state basis. The Company's management also believes the
business of electricity and natural gas are converging and consolidating and
these trends will alter the structure and business practices of companies
serving these markets in the future.
Competition in Wholesale Market. The Federal Energy Policy Act of 1992, the
Public Utility Regulatory Act of 1995 (now the Texas Utilities Code) and
regulations promulgated by the Federal Energy Regulatory Commission (FERC)
contain provisions intended to facilitate the development of a wholesale energy
market. Although Reliant Energy HL&P's wholesale sales traditionally have
accounted for less than 1% of its total revenues, the expansion of competition
in the wholesale electric market is significant in that it has increased the
range of non-utility competitors, such as exempt wholesale generators (EWGs) and
power marketers, in the Texas electric market as well as resulted in fundamental
changes in the operation of the state transmission grid.
In February 1996, the Texas Utility Commission adopted rules granting
third-party users of transmission systems open access to such systems at rates,
terms and conditions comparable to those available to utilities owning such
transmission assets. Under the Texas Utility Commission order implementing the
rule, Reliant Energy HL&P was required to separate, on an operational basis, its
wholesale power marketing operations from the operations of the transmission
grid and, for purposes of transmission pricing, to disclose each of its separate
costs of generation, transmission and distribution.
Within ERCOT, an independent system operator (ISO) manages the state's
electric grid, ensuring system reliability and providing non-discriminatory
transmission access to all power producers and traders. The ERCOT ISO, the first
in the nation, is a key component for implementing the Texas Utility
Commission's overall strategy to create a
42
<PAGE> 47
competitive wholesale market. ERCOT formed an ad hoc committee in early 1998 to
investigate the potential impacts of a competitive retail market on the ISO. The
ERCOT committee report was released in December 1998 and concluded that the
ISO's role and function would necessarily expand in a competitive retail
environment, but the changes required of the ISO to support retail choice should
not impede introduction of retail choice.
Competition in Retail Market. The Company estimates that, since 1978,
cogeneration projects representing approximately one-third of current total peak
generating capability have been built in the Houston area and that, as a result,
Reliant Energy HL&P has seen a reduction of approximately 2,500 MW in customer
load to self-generation. Reliant Energy HL&P has utilized flexible pricing to
respond to situations where large industrial customers have an alternative to
buying power from it, primarily by constructing their own generating facilities.
Under a tariff option approved by the Texas Utility Commission in 1995, Reliant
Energy HL&P was permitted to implement contracts based upon flexible pricing for
up to 700 MW. Currently, this rate is fully subscribed.
Texas law currently does not permit retail sales by unregulated entities
such as cogenerators. The Company anticipates that cogenerators and other
interests will continue to exert pressure to obtain access to the electric
transmission and distribution systems of regulated utilities for the purpose of
making retail sales to customers of regulated utilities.
Legislative Proposals. A number of proposals to restructure the electric
utility industry have been introduced in the 1999 session of the Texas
legislature. If adopted, legislation may permit and encourage alternative
suppliers to compete to serve Reliant Energy HL&P's current rate-regulated
retail customers. The various legislative proposals include provisions governing
recovery of stranded costs and permitting securitization of those costs;
freezing rates until 2002; requiring firm sales of energy to competing retail
electric providers; requiring disaggregation of generation, transmission and
distribution, and retail sales into separate companies and limiting the ability
of existing utilities' affiliates competing for retail electric customers on the
basis of price until they have lost a substantial percentage of their
residential and small commercial load to alternative retail providers. In
addition to the Texas legislative proposals, a number of federal legislative
proposals to promote retail electric competition or restructure the U.S.
electric utility industry have been introduced during the current congressional
session.
At this time, the Company is unable to make any prediction as to whether
any legislation to restructure electric operations or provide retail competition
will be enacted or as to the content or impact on the Company of any legislation
which may be enacted. However, because the proposed legislation is intended to
fundamentally restructure electric utility operations, it is likely that enacted
legislation would have a material impact on the Company.
Stranded Costs. As the U.S. electric utility industry continues its
transition to a more competitive environment, a substantial amount of fixed
costs previously approved for recovery under traditional utility regulatory
practices (including regulatory assets and liabilities) may become "stranded,"
i.e., unrecoverable at competitive market prices. The issue of stranded costs
could be particularly significant with respect to fixed costs incurred in
connection with the past construction of generation plants, such as nuclear
power plants, which, because of their high fixed costs, would not command the
same price for their output as they have in a regulated environment.
In January 1997, the Texas Utility Commission delivered a report to the
Texas legislature on stranded investments in the electric utility industry in
Texas (referred to by the Texas Utility Commission as "Excess Cost Over Market")
(ECOM). In April 1998, the Texas Utility Commission submitted to the Texas
Senate Interim Committee on Electric Utility Restructuring an updated study of
ECOM estimates. Assuming that retail competition is adopted at the beginning of
2002, the updated study estimated that the total amount of stranded costs for
all Texas electric utilities could be $4.5 billion. If instead, retail
competition is adopted one year later, the study estimates statewide ECOM to be
$3.3 billion. Estimates of ECOM vary widely and there is inherent uncertainty in
calculating these costs.
Transition Plan. In June 1998, the Texas Utility Commission approved the
Transition Plan filed by Reliant Energy HL&P in December 1997. The Transition
Plan included base rate credits to residential and certain commercial
43
<PAGE> 48
customers in 1998 and 1999, an overall rate of return cap formula for 1998 and
1999 and approval of accounting procedures designed to accelerate recovery of
stranded costs which may arise under restructuring legislation. The Transition
Plan permits the redirection of depreciation expense to generation assets that
Electric Operations otherwise would apply to transmission, distribution and
general plant assets. In addition, the Transition Plan provides that all
earnings above a 9.844% overall annual rate of return on invested capital be
used to recover Electric Operations' investment in generation assets. In
1998, Reliant Energy HL&P recorded an additional $194 million in depreciation
under the Transition Plan. Certain parties have appealed the order approving the
Transition Plan. For additional information, see Notes 1(f) and 3(b) to the
Company's Consolidated Financial Statements.
COMPETITION -- OTHER OPERATIONs
Natural Gas Distribution competes primarily with alternate energy sources
such as electricity and other fuel sources as well as with providers of energy
conservation products. In addition, as a result of federal regulatory changes
affecting interstate pipelines, it has become possible for other natural gas
suppliers and distributors to bypass Natural Gas Distribution's facilities and
market, sell and/or transport natural gas directly to small commercial and/or
large volume customers.
The Interstate Pipeline segment competes with other interstate and
intrastate pipelines in the transportation and storage of natural gas. The
principal elements of competition among pipelines are rates, terms of service,
and flexibility and reliability of service. Interstate Pipeline competes
indirectly with other forms of energy available to its customers, including
electricity, coal and fuel oils. The primary competitive factor is price.
Changes in the availability of energy and pipeline capacity, the level of
business activity, conservation and governmental regulations, the capability to
convert to alternative fuels, and other factors, including weather, affect the
demand for natural gas in areas served by Interstate Pipeline and the level of
competition for transport and storage services.
Reliant Energy Services competes for sales in its gas and power trading and
marketing business with other natural gas and power merchants, producers and
pipelines based on its ability to aggregate supplies at competitive prices from
different sources and locations and to efficiently utilize transportation from
third-party pipelines and transmission from electric utilities. Reliant Energy
Services also competes against other energy marketers on the basis of its
relative financial position and access to credit sources. This competitive
factor reflects the tendency of energy customers, natural gas suppliers and
natural gas transporters to seek financial guarantees and other assurances that
their energy contracts will be satisfied. As pricing information becomes
increasingly available in the energy trading and marketing business and as
deregulation in the electricity markets continues to accelerate, the Company
anticipates that Reliant Energy Services will experience greater competition and
downward pressure on per-unit profit margins in the energy marketing industry.
Competition for acquisition of international and domestic non-rate
regulated power projects is intense. International and Power Generation compete
against a number of other participants in the non-utility power generation
industry, some of which have greater financial resources and have been engaged
in non-utility power projects for periods longer than the Company and have
accumulated greater portfolios of projects. Competitive factors relevant to the
non-utility power industry include financial resources, access to non-recourse
funding and regulatory factors.
FLUCTUATIONS IN COMMODITY PRICES AND DERIVATIVE INSTRUMENTS
For information regarding the Company's exposure to risk as a result of
fluctuations in commodity prices and derivative instruments, see "Quantitative
and Qualitative Disclosures About Market Risk" in Item 7A of this Report.
ACCOUNTING TREATMENT OF ACES
The Company accounts for its investment in Time Warner Convertible
Preferred Stock (TW Preferred) under the cost method. As a result of the
Company's issuance of the ACES, a portion of the increase in the market value
above $27.7922 per share of Time Warner common stock (the security into which
the TW Preferred is convertible) (TW
44
<PAGE> 49
Common) results in unrealized accounting losses to the Company, pending the
conversion of the Company's TW Preferred into TW Common. For consistency
purposes, the TW Common and related per share prices retroactively reflect a 2
for 1 stock split effective December 15, 1998.
Prior to the conversion of the TW Preferred into TW Common, when the market
price of TW Common increases above $27.7922, the Company records in Other Income
(Expense) an unrealized, non-cash accounting loss for the ACES equal to the
aggregate amount of such increase as applicable to all ACES multiplied by
0.8264. In accordance with generally accepted accounting principles, this
accounting loss (which reflects the unrealized increase in the Company's
indebtedness with respect to the ACES) may not be offset by accounting
recognition of the increase in the market value of the TW Common that underlies
the TW Preferred. Upon conversion of the TW Preferred (which is anticipated to
occur in June 1999 when the preferential dividend on the TW Preferred expires),
the Company will begin recording future unrealized net changes in the market
prices of the TW Common and the ACES as a component of common stock equity and
other comprehensive income.
As of December 31, 1998, the market price of TW Common was $62.062 per
share. Accordingly, the Company recognized an increase of $1.2 billion in 1998
in the unrealized liability relating to its ACES indebtedness (which resulted in
an after-tax earnings reduction of $764 million or $2.69 basic earnings per
share in 1998). The Company believes that the cumulative unrealized loss for the
ACES of approximately $1.3 billion is more than economically offset by the
approximately $1.8 billion unrecorded unrealized gain at December 31, 1998
relating to the increase in the fair value of the TW Common underlying the
investment in TW Preferred since the date of its acquisition. Any gain related
to the increase in fair value of TW Common would be recognized as a component of
net income upon the sale of the TW Preferred or the shares of TW Common into
which such TW Preferred is converted. As of March 11, 1999, the price of TW
Common was $70.75 per share, which would have resulted in the Company
recognizing an additional increase of $329 million in the unrealized liability
represented by its indebtedness under the ACES. The related unrecorded
unrealized gain as of March 11, 1999 would have been computed as an additional
$398 million.
Excluding the unrealized, non-cash accounting loss for ACES, the Company's
retained earnings and total common stock equity would have been $2.3 billion and
$5.2 billion, respectively.
IMPACT OF THE YEAR 2000 ISSUE AND OTHER SYSTEM IMPLEMENTATION ISSUES
Year 2000 Problem. At midnight on December 31, 1999, unless the proper
modifications have been made, the program logic in many of the world's computer
systems will start to produce erroneous results because, among other things, the
systems will incorrectly read the date "01/01/00" as being January 1 of the year
1900 or another incorrect date. In addition, certain systems may fail to detect
that the year 2000 is a leap year. Problems can also arise earlier than January
1, 2000, as dates in the next millennium are entered into non-Year 2000
compliant programs.
Compliance Program. In 1997, the Company initiated a corporate-wide Year
2000 project to address mainframe application systems, information technology
(IT) related equipment, system software, client-developed applications, building
controls and non-IT embedded systems such as process controls for energy
production and delivery. Incorporated into this project were Resources' and
other Company subsidiaries' mainframe applications, infrastructures, embedded
systems and client-developed applications that will not be migrated into
existing or planned Company or Resources systems prior to the year 2000. The
evaluation of Year 2000 issues included those related to significant customers,
key vendors, service suppliers and other parties material to the Company's and
its subsidiaries' operations. In the course of this evaluation, the Company has
sought written assurances from such third parties as to their state of Year 2000
readiness.
State of Readiness. Work has been prioritized in accordance with business
risk. The highest priority has been assigned to activities that would disrupt
the physical delivery of energy (Priority 1); activities that would impact back
office activities such as billing (Priority 2); activities that would cause
inconvenience or productivity loss in normal business operations (e.g. air
conditioning systems and elevators) (Priority 3). All business units have
completed an analysis of critical systems and equipment that control the
production and delivery of energy, as well as corporate, departmental and
personnel systems and equipment. The remediation and replacement work on the
majority of IT
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<PAGE> 50
systems, non-IT systems and infrastructure began in the first quarter of 1998
and is expected to be completed by the second quarter of 1999. Testing of these
systems began in the second quarter of 1998 and is scheduled to be completed in
third quarter of 1999. The following table illustrates the Company's completion
percentages for the Year 2000 activities as of February 28, 1999:
<TABLE>
<CAPTION>
PRIORITY 1 PRIORITY 2 PRIORITY 3
-------------- -------------- ---------------
<S> <C> <C> <C>
Assessment.............................................. 95% 86% 96%
Conversion.............................................. 86% 70% 91%
Testing................................................. 80% 61% 87%
Implementation.......................................... 76% 54% 75%
</TABLE>
Costs to Address Year 2000 Compliance Issues. Based on current internal
studies, as well as recently solicited bids from various computer software
vendors, the Company estimates that the total direct cost of resolving the Year
2000 issue with respect to the Company and its subsidiaries will be between $35
and $40 million. This estimate includes approximately $7 million related to
salaries and expenses of existing employees and approximately $3 million in
hardware purchases that the Company expects to capitalize. In addition, the $35
to $40 million estimate includes approximately $2 million spent prior to 1998
and approximately $12 million during 1998. The remaining costs related to
resolving the Year 2000 issue are expected to be expended in 1999.
The Company expects to fund these expenditures through internal sources.
In September 1997, the Company entered into an agreement with SAP America,
Inc. (SAP) to license SAP proprietary R/3 enterprise software. The licensed
software includes customer care, finance and accounting, human resources,
materials management and service delivery components. The Company's purchase of
this software license and related computer hardware is part of its response to
changes in the electric utility and energy services industries, as well as
changes in the Company's businesses and operations resulting from the
acquisition of Resources and the Company's expansion into the energy trading and
marketing business. Although it is anticipated that the implementation of the
SAP system will have the incidental effect of negating the need to modify many
of the Company's computer systems to accommodate the Year 2000 problem, the
Company does not deem the costs of the SAP system as directly related to its
Year 2000 compliance program. Portions of the SAP system were implemented in
December 1998 and March 1999, and it is expected that the final portion of the
SAP system will be fully implemented by July 2000. The estimated costs of
implementing the SAP system is approximately $182 million, inclusive of internal
costs. In 1998, the Company and its subsidiaries spent $108 million of such
costs. In 1999, the Company and its subsidiaries expect to spend $59 million
with the remaining amounts to be spent in 2000.
The estimated Year 2000 project costs do not give effect to any future
corporate acquisitions or divestitures made by the Company or its subsidiaries.
Risks and Contingency Plans. The major systems which pose the greatest Year
2000 risks for the Company and its subsidiaries if implementation of the Year
2000 compliance program is not successful are the process control systems for
energy delivery systems; the time in use, demand and recorder metering system
for commercial and industrial customers; the outage analysis system; and the
power billing systems. The potential problems related to these systems are
temporary electric service interruptions to customers, temporary interruptions
in revenue data gathering and temporary poor customer relations resulting from
delayed billing. Although the Company does not believe that this scenario will
occur, the Company has considerable experience responding to emergency
situations, including computer failure. Existing emergency operations, disaster
recovery and business continuation plans are being enhanced to ensure
preparedness and to mitigate the long-term effect of such a scenario.
The North American Electric Reliability Council (NERC) is coordinating
electric utility industry contingency planning on a national level. Additional
contingency planning is being done at the regional electric reliability council
level. Reliant Energy HL&P filed a draft Year 2000 Contingency Plan with NERC
and with the Texas Utility Commission in December 1998. The draft plan addresses
restoration of electric service and related business processes, and is designed
to work in conjunction with the Emergency Operating Plan and with the plans of
NERC and ERCOT.
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<PAGE> 51
A final contingency plan is scheduled to be complete by June 30, 1999. In
addition, Reliant Energy HL&P will participate in industry preparedness drills,
such as the two NERC drills scheduled to be held on April 9, 1999 and September
9, 1999.
The existing business continuity disaster recovery and emergency operations
plans are being reviewed and enhanced, and where necessary, additional plans
will be developed to include mitigation strategies and action plans specifically
addressing potential Year 2000 scenarios. The expected completion date for these
plans is June 30, 1999.
In order to assist in preparing for and mitigating the foregoing scenarios,
the Company intends to complete all mission critical Year 2000 remediation and
testing activity by the end of the second quarter of 1999. In addition, the
Company has initiated Year 2000 communications with significant customers, key
vendors, service suppliers and other parties material to the Company's
operations and is diligently monitoring the progress of such third parties' Year
2000 projects. The Company expects to meet with mission-critical third parties,
including suppliers, in order to ascertain and assess the relative risks of
Year-2000-related issues, and to mitigate such risks. Notwithstanding the
foregoing, the Company cautions that (i) the nature of testing is such that it
cannot comprehensively address all future combinations of dates and events and
(ii) it is impossible for the Company to assess with precision or certainty the
compliance of third parties with Year 2000 remediation efforts. Due to the
speculative and uncertain nature of contingency planning, there can be no
assurance that such plans actually will be sufficient to reduce the risk of
material impacts on the Company's and its subsidiaries' operations.
RISKS OF INTERNATIONAL OPERATIONS
The Company's international operations are subject to various risks
incidental to investing or operating in emerging market countries. These risks
include political risks, such as governmental instability, and economic risks,
such as fluctuations in currency exchange rates, restrictions on the
repatriation of foreign earnings and/or restrictions on the conversion of local
currency earnings into U.S. dollars. The Company's international operations are
also highly capital intensive and, thus, dependent to a significant extent on
the continued availability of bank financing and other sources of capital on
commercially acceptable terms.
Impact of Currency Fluctuations on Company Earnings. The Company, through
Reliant Energy International's subsidiaries, owns 11.69% of the stock of Light
and, through its investment in Light, an 8.753% interest in the stock of
Metropolitana Electricidade de Sao Paulo S.A. (Metropolitana). The Company
accounts for its investment in Light under the equity method of accounting and
records its proportionate share, based on stock ownership, in the net income of
Light and its affiliates (including Metropolitana) as part of the Company's
consolidated net income.
At December 31, 1998, Light and Metropolitana had total borrowings of
approximately $3.2 billion denominated in non-local currencies. Because of the
devaluation of the Brazilian real subsequent to December 31, 1998, Light and
Metropolitana are expected to record a charge to March 31, 1999 earnings that
reflects the increase in the liability represented by their non-local currency
denominated bank borrowings relative to the Brazilian real. Because the Company
uses the Brazilian real as the functional currency in which it reports Light's
equity earnings, the resulting decrease in Light's earnings will also be
reflected in the Company's consolidated earnings to the extent of the Company's
11.69% ownership interest in Light. At December 31, 1998, one U. S. dollar could
be exchanged for 1.21 Brazilian reais. Using the exchange rate of 2.06 Brazilian
reais in effect at the end of February, and the average exchange rate in effect
since the end of the year, the Company estimates that its share of the after-tax
charge to be recorded by Light would be approximately $125 million. This
estimate does not reflect the possibility of additional fluctuations in the
exchange rate and does not include other non-debt-related impacts of Brazil's
currency devaluation on Light's and Metropolitana's future earnings.
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<PAGE> 52
None of Light's or Metropolitana's tariff adjustment mechanisms are
directly indexed to the U.S. dollar or other non-local currencies. Each company
currently is evaluating various options including regulatory rate relief to
mitigate the impact of the devaluation of the Brazilian real. For example, the
long-term concession contracts under which Light and Metropolitana operate
contain mechanisms for adjusting electricity tariffs to reflect changes in
operating costs resulting from inflation. If the devaluation of the Brazilian
real results in an increase in the local rate of inflation and if an adjustment
to tariff rates is made promptly to reflect such increase, the Company believes
that the financial results of Light and Metropolitana should be protected, at
least in part, from the effects of devaluation. However, there can be no
assurance the implementation of such tariff adjustments will be timely or that
the economic impact of the devaluation will be completely reflected in increased
inflation rates.
Certain of Reliant Energy International's other foreign electric
distribution companies have incurred U.S. dollar and other non-local currency
indebtedness (approximately $71 million at December 31, 1998). For further
analysis of foreign currency fluctuations in the Company's earnings and cash
flows, see "Quantitative and Qualitative Disclosures About Market Risk --
Foreign Currency Exchange Rate Risk" in Item 7A of this Form 10-K.
Impact of Foreign Currency Devaluation on Project Capital Resources. In the
first quarter of 1999, approximately $117 million of Metropolitana's U.S. dollar
denominated debt will mature. In the second quarter of 1999, approximately $980
million of Light's and approximately $696 million of Metropolitana's U.S. and
non-local currency denominated bank debt will mature. In March 1999, Light
refinanced approximately $130 million of its U.S. dollar denominated debt
through a local - currency denominated loan. The ability of Light and
Metropolitana to repay or refinance their debt obligations at maturity is
dependent on many factors, including local and international economic conditions
prevailing at the time such debt matures.
If economic conditions in the international markets continue to be
unsettled or deteriorate, it is possible that Light, Metropolitana and the other
foreign electric distribution companies in which the Company holds investments
might encounter difficulties in refinancing their debt (both local currency and
non-local currency borrowings) on terms and conditions that are commercially
acceptable to them and their shareholders. In such circumstances, in lieu of
declaring a default or extending the maturity, it is possible that lenders might
seek to require, among other things, higher borrowing rates, and additional
equity contributions and/or increased levels of credit support from the
shareholders of such entities. The availability or terms of refinancing such
debt cannot be assured.
Currency fluctuation and instability affecting Latin America may also
adversely affect Reliant Energy International's ability to refinance its equity
investments with debt. In 1998, Reliant Energy International invested $411
million in Colombia and El Salvador. As of January 1999, $100 million of these
investments were refinanced with debt. Reliant Energy International intends to
refinance approximately $75 million more of such initial investments with debt.
ENVIRONMENTAL EXPENDITURES
The Company and its subsidiaries, including Resources, are subject to
numerous environmental laws and regulations, which require them to incur
substantial costs to operate existing facilities, construct and operate new
facilities, and mitigate or remove the effect of past operations on the
environment.
Clean Air Act Expenditures. The Company expects the majority of capital
expenditures associated with environmental matters to be incurred by Electric
Operations in connection with new emission limitations under the Federal Clean
Air Act (Clean Air Act) for oxides of nitrogen (NOx). The standards applicable
to Electric Operations' generating units in the Houston, Texas area will become
effective in November 1999. NOx reduction costs incurred by Electric Operations
totaled approximately $7 million in 1998. The Company estimates that Electric
Operations will incur approximately $8 million in 1999 and $10 million in 2000
for such expenditures. The Texas Natural Resources Conservation Commission
(TNRCC) has indicated that additional NOx reduction will be required after 2000;
however, since the magnitude and timing of these reductions have not yet been
established, it is impossible for the Company to estimate a reasonable range of
such expenditures at this time.
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<PAGE> 53
In 1998, the Wholesale Energy spent approximately $100,000 in order to
comply with NOx reduction with respect to Southern California generating
facilities acquired by Power Generation from Southern California Edison (SCE) in
1998. In 1999, based on existing requirements, the Company projects that it will
spend an additional $100,000 on NOx reduction standards with respect to such
plants and approximately $1 million on continuous emission monitoring system
upgrades for such plants.
Site Remediation Expenditures. From time to time the Company and its
subsidiaries have received notices from regulatory authorities or others
regarding their status as potentially responsible parties in connection with
sites found to require remediation due to the presence of environmental
contaminants.
The Company's identified sites with respect to which it may be claimed to
have a remediation liability include several sites for which there is a lack of
current available information, including the nature and magnitude of
contamination, and the extent, if any, to which the Company may be held
responsible for contributing to any costs incurred for remediating these sites.
Thus, no reasonable estimate of cleanup costs can now be made for these sites.
Based on currently available information, the Company believes that such costs
ultimately will not materially affect its financial position, results of
operations or cash flows. There can be no assurance, however, that future
developments, including additional information about existing sites or the
identification of new sites, will not require material revisions to such
estimates. For information about specific sites that are the subject of
remediation claims, see Note 12(h) to the Company's Consolidated Financial
Statements and Note 8(g) to Resources' Consolidated Financial Statements, each
of which is incorporated herein by reference.
Mercury Contamination. Like other natural gas pipelines, Resources'
pipeline operations have in the past employed elemental mercury in meters used
on its pipelines. Although the mercury has now been removed from the meters, it
is possible that small amounts of mercury have been spilled at some of those
sites in the course of normal maintenance and replacement operations and that
such spills have contaminated the immediate area around the meters with
elemental mercury. Such contamination has been found by Resources at some sites
in the past, and Resources has conducted remediation at sites found to be
contaminated. Although Resources is not aware of additional specific sites, it
is possible that other contaminated sites exist and that remediation costs will
be incurred for such sites. Although the total amount of such costs cannot be
known at this time, based on experience of Resources and others in the natural
gas industry to date and on the current regulations regarding remediation of
such sites, the Company and Resources believe that the cost of any remediation
of such sites will not be material to the Company's or Resources' financial
position, results of operations or cash flows.
Other. In addition, the Company has been named as a defendant in litigation
related to such sites and in recent years has been named, along with numerous
others, as a defendant in several lawsuits filed by a large number of
individuals who claim injury due to exposure to asbestos while working at sites
along the Texas Gulf Coast. Most of these claimants have been workers who
participated in construction of various industrial facilities, including power
plants, and some of the claimants have worked at locations owned by the Company.
The Company anticipates that additional claims like those received may be
asserted in the future and intends to continue its practice of vigorously
contesting claims which it does not consider to have merit. Although their
ultimate outcome cannot be predicted at this time, the Company does not believe,
based on its experience to date, that these matters, either individually or in
the aggregate, will have a material adverse effect on the Company's financial
position, results of operations or cash flows.
OTHER CONTINGENCIES
For a description of certain other legal and regulatory proceedings
affecting the Company and its subsidiaries, see Notes 3, 4, 5 and 12 to the
Company's Consolidated Financial Statements and Note 8 to Resources'
Consolidated Financial Statements, which notes are incorporated herein by
reference.
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<PAGE> 54
LIQUIDITY AND CAPITAL RESOURCES
COMPANY CONSOLIDATED CAPITAL REQUIREMENTS
The liquidity and capital requirements of the Company and its subsidiaries
are affected primarily by capital programs and debt service requirements. The
capital requirements for 1998 were, and as estimated for 1999 through 2003 are,
as follows (in millions):
<TABLE>
<CAPTION>
-------------------------------------------------------------------------
1998 1999 2000 2001 2002 2003
----------- ----------- ------------ ----------- ----------- ------------
<S> <C> <C> <C> <C> <C> <C>
Electric capital and nuclear fuel
(excluding allowance for funds used
during construction) (AFUDC).......... $ 429 $ 490 $ 432 $ 379 $ 370 $ 370
Natural Gas Distribution(3).............. 162 185 173 172 168 169
Interstate Pipeline(3)................... 59 30 28 17 17 17
Wholesale Energy (excluding capitalized
interest)(2).......................... 364 154 156 25 12 10
International (excluding capitalized
interest)(2) ......................... 427 3 2 3
Corporate................................ 30 64 42 53 55 54
Maturities of long-term debt, preferred
stock and minimum capital lease
payments(3)........................... 240 402 2,758 438 1,895 199
------- -------- -------- -------- -------- --------
Total(1)............................ $ 1,711 $ 1,328 $ 3,591 $ 1,087 $ 2,517 $ 819
======= ======== ======== ======== ======== ========
</TABLE>
- ----------
(1) Expenditures in the table do not reflect expenditures associated with the
Year 2000 issue. For a discussion of these expenditures, see "--Certain
Factors Affecting Future Earnings of the Company and its Subsidiaries --
Impact of the Year 2000 Issue and Other System Implementation Issues."
(2) Expenditures in the table reflect only expenditures made or to be made
under existing contractual commitments entered into by International and
Wholesale Energy. The Company expects that Reliant Energy International and
Power Generation will continue to participate as bidders in future
acquisitions of independent power projects, privatizations of generation
and distribution facilities and sales of generating assets. International
and Wholesale Energy capital requirements are expected to be met through
advances from the Company, the proceeds of project financings and the
proceeds of borrowings at the Company's finance subsidiaries. Additional
capital expenditures are dependent upon the nature and extent of future
project commitments (some of which may be substantial).
(3) All of the capital requirements for Natural Gas Distribution and Interstate
Pipelines represent requirements at Resources. Wholesale Energy
requirements allocable to Resources for the respective periods shown are
$21 million, $45 million, $23 million, $16 million, $12 million and $10
million. The components of "Maturities of long-term debt, preferred stock
and minimum capital lease payments" allocable to Resources for the
respective periods shown are $227 million, $207 million, $228 million, $151
million, $7 million and $7 million.
For the year ended December 31, 1998, the Company's net cash provided by
operating activities increased $315 million over the same period in 1997. The
increase in net cash from operating activities is due primarily to (i)
incremental cash flow provided by the business segments purchased in the
Resources acquisition, (ii) increased sales at Electric Operations due to
unusually hot weather during the second and third quarters of 1998 and (iii) the
receipt of a refund of federal income taxes and related interest income.
Net cash used in investing activities decreased $752 million for the year
ended December 31, 1998, compared to the same period in 1997, due to the
Resources acquisition. Investing activities for the year ended December 31, 1998
included (i) the acquisition and construction of non-rate regulated power
generation projects, (ii) the acquisition of investments in foreign electric
distribution systems and (iii) the sale of an investment in an Argentine
electric distribution company.
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<PAGE> 55
Net cash used in financing activities for the year ended December 31, 1998
reflected a $218 million outflow compared to an inflow of $914 million in the
same period in 1997. The cash inflow in 1997 included $1 billion in proceeds
from the issuance of the ACES and the proceeds from the issuance of $1.4 billion
in commercial paper borrowings used to finance a portion of the cost of the
Resources acquisition. The proceeds from the ACES were used to retire $1 billion
of commercial paper borrowings.
In June 1998, the Company repaid at maturity $5 million of floating-rate
pollution control revenue bonds issued on its behalf. In February 1999, the
Company repaid at maturity $170.5 million of medium-term notes collateralized by
first mortgage bonds.
The Company has approximately $400 million of consolidated debt maturing in
1999.
During 1998, Resources repaid at maturity $76 million of medium-term notes
and a $150 million term loan. In March 1998, Resources satisfied the $6.5
million sinking fund requirement for its 6% convertible subordinated debentures
due 2012 using debentures purchased in 1996 and 1997. During 1998, Resources
purchased and retired $6.7 million aggregate principal amount of its 6%
convertible subordinated debentures due 2012 at an average purchase price of
97.3% of the aggregate principal amount plus accrued interest. During 1999,
Resources purchased and retired $5.8 million aggregate principal amount of its
6% convertible subordinated debentures due 2012 at an average purchase price of
98.4% of the aggregate principal amount plus accrued interest. The debentures
purchased in 1998 and 1999 are expected to be used to satisfy the March 1999,
March 2000 and March 2001 sinking fund requirements. Resources has $200 million
of debt maturing in July 1999.
During 1998, a subsidiary of Reliant Energy International retired $13.1
million of its debt under a loan facility established in connection with the
financing of the acquisition costs of Light. Approximately $22.3 million of debt
under this loan facility is scheduled to be retired in 1999.
COMPANY CONSOLIDATED SOURCES OF CAPITAL RESOURCES AND LIQUIDITY
At December 31, 1998, FinanceCo, a limited partnership subsidiary of the
Company, had a $1.6 billion revolving credit facility (FinanceCo Facility)
terminating in 2002. At December 31, 1998, the FinanceCo Facility supported $1.4
billion in commercial paper borrowings having a weighted average interest rate
of 5.88%. For additional information regarding the FinanceCo Facility, see Note
8(c) to the Company's Consolidated Financial Statements.
At December 31, 1998, the Company, exclusive of Resources and other
subsidiaries, had a revolving credit facility of $200 million which could be
used to support the Company's issuance of up to $200 million of commercial
paper. At December 31, 1998, the Company had no loans outstanding under the
facility and no commercial paper borrowings.
In March 1998, Resources replaced its $400 million revolving credit
facility with a five-year $350 million revolving credit facility (Resources
Credit Facility), which could be used to support Resources' issuance of up to
$350 million of commercial paper. At December 31, 1998, Resources had no loans
outstanding under the unsecured facility and no commercial paper borrowings. The
Company expects to amend the Resources Credit Facility in March 1999 to include
a $65 million sub-facility under which letters of credit may be obtained.
Resources previously obtained letters of credit under a $65 million committed
facility which was terminated in December 1998. Subsequent to the termination
and prior to the amendment to the Credit Facility, Resources obtained letters of
credit under an uncommitted line.
At December 31, 1998, Resources had a trade receivables facility of $300
million under which receivables of $300 million had been sold. For additional
information regarding Resources' Credit Facilities, see Note 8(g) to the
Company's Consolidated Financial Statements.
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<PAGE> 56
In March 1998, a limited partnership special purpose subsidiary of the
Company (FinanceCo II) executed a $150 million credit agreement with a bank
(FinanceCo II Facility). Proceeds from $150 million of borrowings under the
FinanceCo II Facility were used to fund a portion of Wholesale Energy's April
1998 purchase of four electric generation plants. Borrowings under the FinanceCo
II Facility were repaid at maturity in March 1999 with commercial paper issued
at FinanceCo. For additional information regarding the FinanceCo II Facility,
see Note 8(c) to the Company's Consolidated Financial Statements.
In January 1998, 5.25% ($29.7 million) and 5.15% ($75 million) pollution
control revenue refunding bonds were issued on behalf of the Company by the
Matagorda County Navigation District Number One (MCND). Proceeds from the
issuance were used in February 1998 to redeem, at 102% of the $104.7 million
aggregate principal amount, pollution control revenue bonds.
In February 1998, Resources issued $300 million of 6 1/2 % debentures due
February 1, 2008. The proceeds from the sale of the debentures were used to
repay short-term indebtedness of Resources, including the short-term
indebtedness incurred in connection with the purchase in 1997 of $101.4 million
of its 10% debentures and the repayment of $53 million of Resources debt that
matured in December 1997 and January 1998.
In February 1998, 5 1/8% pollution control revenue refunding bonds
aggregating $290 million were issued on behalf of the Company by the Brazos
River Authority (BRA). Proceeds from the issuance were used in May 1998 to
redeem, at 102% of the $290 million aggregate principal amount, pollution
control revenue bonds.
In September 1998, 4.90% pollution control revenue refunding bonds
aggregating $68.7 million were issued on behalf of the Company by the BRA.
Proceeds from the issuance were used in October 1998 to redeem, at 102% of the
$68.7 million aggregate principal amount, pollution control revenue bonds.
In November 1998, the Company effected a change in the method of interest
rate determination on the MCND Series 1997 pollution control revenue refunding
bonds due November 2028 ($68 million aggregate principal amount outstanding) and
the BRA Series 1997 pollution control revenue refunding bonds due November 2018
($50 million aggregate principal amount outstanding). The method by which
interest on the bonds is determined changed from a floating rate mode to a
long-term fixed rate mode. The interest rate on the MCND Series 1997 bonds and
the BRA Series 1997 bonds until their maturity is 5 1/8% and 5.05%,
respectively.
In November 1998, Resources sold $500 million of its 6 3/8% Term Enhanced
ReMarketable Securities (TERM Notes). The net proceeds from the offering were
used for general corporate purposes, including the repayment of (i) $178.5
million of Resources' outstanding commercial paper and (ii) a $150 million term
loan of Resources that matured on November 13, 1998. For additional information
regarding the TERM Notes offering, see Note 8 (h) to the Company's Consolidated
Financial Statements and Note 4(b) to Resources' Consolidated Financial
Statements.
In December 1997, Sempra Energy Resources and Power Generation formed El
Dorado Energy, a joint venture formed to build, own and operate a 492MW natural
gas power plant in Boulder City, Nevada. Power Generation invested $25 million
and $2 million in El Dorado in 1998 and 1997, respectively. Total cost for the
project is estimated to be $263 million. In October 1998, El Dorado Energy
obtained a 15 year, $158 million non-recourse loan to finance the project.
The loan represents approximately 60% of the estimated total project cost.
In February 1999, a Delaware statutory business trust (REI Trust I)
established by the Company issued $375 million of preferred securities. The
preferred securities have a distribution rate of 7.20% payable quarterly in
arrears, a stated liquidation amount of $25 per preferred security and must be
redeemed by March 2048. REI Trust I sold the preferred securities to the public
and used the proceeds to purchase $375 million aggregate principal amount of
subordinated debentures (REI Debentures) from the Company having an interest
rate corresponding to the distribution rate of the preferred securities and a
maturity date corresponding to the mandatory redemption date of the preferred
securities. Proceeds from the sale of the REI Debentures were used by the
Company for general corporate purposes, including the repayment of short-term
debt. For further discussion, see Note 16(b) to the Company's Consolidated
Financial Statements.
At December 31, 1998, the Company had shelf registration statements
providing for the issuance of $230 million aggregate liquidation value of its
preferred stock and $580 million aggregate principal amount of its debt
securities. In the first quarter of 1999, the Company registered $500 million of
trust preferred securities and junior subordinated debt securities, of which
$125 million remains available for issuance. The issuance of all securities
registered by the Company and its affiliates is subject to market and other
conditions.
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<PAGE> 57
The Company owns 11 million shares of non-publicly traded TW Preferred. The
TW Preferred, which is entitled to cumulative annual dividends of $3.75 per
share until July 6, 1999, and is currently convertible at the option of the
Company into 45.8 million shares of Time Warner common stock. The Company's
ability to transfer, sell or pledge the shares of TW Preferred is not restricted
pursuant to the terms of the ACES. The Company reviews its investment in Time
Warner on a regular basis and does not expect to maintain its investment in Time
Warner indefinitely. For additional information regarding the Company's
investment in Time Warner securities, see Notes 1(n) and (e) to the Company's
Consolidated Financial Statements.
For information regarding the potential impact of foreign currency
devaluation on the Company's future liquidity needs, see "--Certain Factors
Affecting Future Earnings of the Company's and its Subsidiaries -- Risks of
International Operations."
The Company and its subsidiaries participate from time to time in
competitive bids for generating and distribution assets through its Wholesale
Energy and International segments. Although the Company believes that its
current level of cash and borrowing capability along with future cash flows from
operations are sufficient to meet the existing operational needs of its
businesses, the Company may, when it deems necessary, or when it acquires and
operates new businesses and assets, supplement its available cash resources by
seeking funds in the equity or debt markets.
NEW ACCOUNTING ISSUES
In 1998, the Company and Resources adopted SFAS No. 130, "Reporting
Comprehensive Income" (SFAS No. 130), SFAS No. 131, "Disclosures about Segments
of an Enterprise and Related Information" (SFAS No. 131) and SFAS No. 132,
"Employers Disclosures about Pensions and Other Postretirement Benefits" (SFAS
No. 132). For further discussion of these accounting statements, see Note 15 to
the Company's Consolidated Financial Statements and Note 9 to Resources'
Consolidated Financial Statements.
In 2000, the Company and Resources expect to adopt SFAS No. 133,
"Accounting for Derivative Instruments and Hedging Activities" (SFAS No. 133),
which establishes accounting and reporting standards for derivative instruments,
including certain derivative instruments embedded in other contracts
(collectively referred to as derivatives) and for hedging activities. The
Company is in the process of determining the effect of adoption of SFAS No. 133
on its consolidated financial statements.
In December 1998, The Emerging Issues Task Force of the Financial
Accounting Standards Board reached consensus on Issue 98-10, "Accounting for
Contracts Involved in Energy Trading and Risk Management Activities" (EITF Issue
98-10). EITF Issue 98-10 requires energy trading contracts to be recorded at
fair value on the balance sheet, with the changes in fair value included in
earnings. EITF Issue 98-10 is effective for fiscal years beginning after
December 15, 1998. The Company expects to adopt EITF Issue 98-10 in the first
quarter of 1999. The Company does not expect the implementation of EITF Issue
98-10 to be material to its consolidated financial statements.
53
<PAGE> 58
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
INTEREST RATE RISK
The Company and its subsidiaries have long-term debt, Company/ Resources
obligated mandatorily redeemable preferred securities of subsidiary trusts
holding solely junior subordinated debentures of the Company/Resources (Trust
Securities), securities held in the Company's nuclear decommissioning trust,
bank facilities, certain lease obligations and interest rate swaps which subject
the Company, Resources and certain of their subsidiaries to the risk of loss
associated with movements in market interest rates.
At December 31, 1998, the Company and certain of its subsidiaries had
issued fixed-rate long-term debt (excluding ACES) and Trust Securities
aggregating $5.0 billion in principal amount and having a fair value of $5.2
billion. These instruments are fixed-rate and, therefore, do not expose the
Company and its subsidiaries to the risk of earnings loss due to changes in
market interest rates (see Notes 8 and 9 to the Company's Consolidated Financial
Statements). However, the fair value of these instruments would increase by
approximately $260.6 million if interest rates were to decline by 10% from their
levels at December 31, 1998. In general, such an increase in fair value would
impact earnings and cash flows only if the Company and its subsidiaries were to
reacquire all or a portion of these instruments in the open market prior to
their maturity.
The Company and certain of its subsidiaries' floating-rate obligations
aggregated $1.8 billion at December 31, 1998 (see Note 8 to the Company's
Consolidated Financial Statements), inclusive of (i) amounts borrowed under
short-term and long-term credit facilities of the Company and its subsidiaries
(including the issuance of commercial paper supported by such facilities), (ii)
borrowings underlying Resources' receivables facility and (iii) amounts subject
to a master leasing agreement of Resources under which lease payments vary
depending on short-term interest rates. These floating-rate obligations expose
the Company, Resources and their subsidiaries to the risk of increased interest
and lease expense in the event of increases in short-term interest rates. If the
floating rates were to increase by 10% from December 31, 1998 levels, the
Company's consolidated interest expense and expense under operating leases would
increase by a total of approximately $0.9 million each month in which such
increase continued.
As discussed in Notes 1(o), 4(c) and 13 to the Company's Consolidated
Financial Statements, the Company contributes $14.8 million per year to a trust
established to fund the Company's share of the decommissioning costs for the
South Texas Project. The securities held by the trust for decommissioning costs
had an estimated fair value of $119.1 million as of December 31, 1998, of which
approximately 44% were fixed-rate debt securities that subject the Company to
risk of loss of fair value with movements in market interest rates. If interest
rates were to increase by 10% from their levels at December 31, 1998, the
decrease in fair value of the fixed-rate debt securities would not be material
to the Company. In addition, the risk of an economic loss is mitigated at this
time as a result of the Company's regulated status. Any unrealized gains or
losses are accounted for in accordance with SFAS No. 71 as a regulatory
asset/liability because the Company believes that its future contributions which
are currently recovered through the rate-making process will be adjusted for
these gains and losses.
Certain subsidiaries of the Company have entered into interest rate swaps
for the purpose of decreasing the amount of debt subject to interest rate
fluctuations. At December 31, 1998, these interest rate swaps had an aggregate
notional amount of $75.4 million, which the Company could terminate at a cost of
$3.2 million (see Notes 2 and 13 to the Company's Consolidated Financial
Statements). An increase of 10% in the December 31, 1998 level of interest rates
would not increase the cost of termination of the swaps by a material amount to
the Company. Swap termination costs would impact the Company's and its
subsidiaries' earnings and cash flows only if all or a portion of the swap
instruments were terminated prior to their expiration.
54
<PAGE> 59
As discussed in Note 8(h) to the Company's Consolidated Financial
Statements, Resources sold $500 million aggregate principal amount of its 6 3/8%
TERM Notes which included an embedded option to remarket the securities. The
option is expected to be exercised in the event that the ten-year Treasury rate
in 2003 is below 5.66%. At December 31, 1998, the Company could terminate the
option at a cost of $30.7 million. A decrease of 10% in the December 31, 1998
level of interest rates would not increase the cost of termination of the option
by a material amount to the Company.
The change in exposure to loss in earnings and cash flows related to
interest rate risk from December 31, 1997 to December 31, 1998 is not material
to the Company.
EQUITY MARKET RISK
The Company holds an investment in TW Preferred which is convertible into
Time Warner common stock (TW Common) as described in "Management's Discussion
and Analysis of Financial Condition and Results of Operations of the Company --
Certain Factors Affecting Future Earnings of the Company and its Subsidiaries --
Accounting Treatment of ACES" in Item 7 of this Form 10-K. As a result, the
Company is exposed to losses in the fair value of this security. For purposes of
analyzing market risk in this Item 7A, the Company assumed that the TW Preferred
was converted into TW Common. In addition, Resources' investment in the common
stock of Itron, Inc. (Itron) exposes the Company and Resources to losses in the
fair value of Itron common stock. A 10% decline in the market value per share of
TW Common and Itron common stock from the December 31, 1998 levels would result
in a loss in fair value of approximately $284.4 million and $1.1 million,
respectively.
The Company's and its subsidiaries' ability to realize gains and losses
related to the TW Preferred and the Itron common stock is limited by the
following: (i) the TW Preferred is not publicly traded and its sale is subject
to certain limitations and (ii) the market for the common stock of Itron is
fairly illiquid.
The ACES expose the Company to accounting losses as the Company is required
to record in Other Income (Expense) an unrealized accounting loss equal to (i)
the aggregate amount of the increase in the market price of TW Common above
$27.7922 as applicable to all ACES multiplied by (ii) 0.8264. Prior to the
conversion of the TW Preferred into TW Common, such loss would affect earnings.
After conversion, such loss would be recognized as an adjustment to common stock
equity through a reduction of other comprehensive income. However, there would
be an offsetting increase in common stock equity through an increase in
accumulated other comprehensive income on the Company's Statements of
Consolidated Retained Earnings and Comprehensive Income for the fair value
increase in the investment in TW Common. For additional information on the
accounting treatment of the ACES and related accounting losses recorded in 1998,
see Note 1(n) to the Company's Consolidated Financial Statements. An increase of
15% in the price of the TW Common above its December 31, 1998 market value of
$62.062 per share would result in the recognition of an additional unrealized
accounting loss (net of tax) of approximately $229.1 million. The Company
believes that this additional unrealized loss for the ACES would be more than
economically hedged by the unrecorded unrealized gain relating to the increase
in the fair value of the TW Common underlying the investment in TW Preferred
since the date of its acquisition.
For a discussion of the non-cash, unrealized accounting loss recorded in
1998 and 1997 related to the ACES, see "-- Certain Factors Affecting Future
Earnings of the Company and its Subsidiaries -- Accounting Treatment of ACES" in
Item 7 of this Form 10-K.
As discussed above under "-- Interest Rate Risk," the Company contributes
to a trust established to fund the Company's share of the decommissioning costs
for the South Texas Project which held debt and equity securities as of December
31, 1998. The equity securities expose the Company to losses in fair value. If
the market prices of the individual equity securities were to decrease by 10%
from their levels at December 31, 1998, the resulting loss in fair value of
these securities would not be material to the Company. Currently, the risk of an
economic loss is mitigated as a result of the Company's regulated status as
discussed above under "--Interest Rate Risk."
55
<PAGE> 60
FOREIGN CURRENCY EXCHANGE RATE RISK
As further described in "Certain Factors Affecting Future Earnings of the
Company and Its Subsidiaries -- Risks of International Operations" in Item 7 of
this Form 10-K, the Company, through Reliant Energy International invests in
certain foreign operations which to date have been primarily in South America.
As of December 31, 1998, the Company's Consolidated Balance Sheets reflected
$1.1 billion of foreign investments, a substantial portion of which represent
investments accounted for under the equity method. These foreign investments
expose the Company to risk of loss in earnings and cash flows due to the
fluctuation in foreign currencies relative to the Company's consolidated
reporting currency, the U.S. dollar. The Company accounts for adjustments
resulting from translation of its investments with functional currencies other
than the U.S. dollar as a charge or credit directly to a separate component of
stockholders' equity. For further discussion of the accounting for foreign
currency adjustments, see Note 1(p) in the Notes to the Company's Consolidated
Financial Statements. The cumulative translation loss of $34 million, recorded
as of December 31, 1998, will be realized as a loss in earnings and cash flows
only upon the disposition of the related investment. The foreign currency loss
in earnings and cash flows related to debt obligations held by foreign
operations in currencies other than their own functional currencies was not
material to the Company as of December 31, 1997.
In addition, certain of Reliant Energy International's foreign operations
have entered into obligations in currencies other than their own functional
currencies which expose the Company to a loss in earnings. In such cases, as the
respective investment's functional currency devalues relative to the non-local
currencies, the Company will record its proportionate share of its investments'
foreign currency transaction losses related to the non-local currency
denominated debt. At December 31, 1998, Light and Metropolitana had borrowings
of approximately $3.2 billion denominated in non-local currencies. Because of
the devaluation of the Brazilian real subsequent to December 31, 1998, Light and
Metropolitana are expected to record a charge to earnings for the quarter ended
March 31, 1999, primarily related to foreign currency transaction losses on
their non-local currency denominated debt. For further discussion and analysis
of the possible effect on the Company's Consolidated Financial Statements, see
"Certain Factors Affecting Future Earnings of the Company and Its Subsidiaries
- -- Risks of International Operations" in Item 7 of this Form 10-K.
The company attempts to manage and mitigate this foreign risk by properly
balancing the higher cost of financing with local denominated debt against the
risk of devaluation of that local currency and including a measure of the risk
of devaluation in all its financial plans. In addition, where possible, Reliant
Energy International attempts to structure its tariffs and revenue contracts to
ensure some measure of adjustment due to changes in inflation and currency
exchange rates; however, there can be no assurance that such efforts will
compensate for the full effect of currency devaluation, if any.
ENERGY COMMODITY PRICE RISK
As further described in Note 2 to the Company's Consolidated Financial
Statements, certain of the Company's subsidiaries utilize a variety of
derivative financial instruments (Derivatives), including swaps and
exchange-traded futures and options, as part of the Company's overall hedging
strategies and for trading purposes. To reduce the risk from the adverse effect
of market fluctuations in the price of electric power, natural gas, crude oil
and refined products and related transportation, Resources and certain
subsidiaries of the Company and Resources enter into futures transactions,
forward contracts, swaps and options (Energy Derivatives) in order to hedge
certain commodities in storage, as well as certain expected purchases, sales and
transportation of energy commodities (a portion of which are firm commitments at
the inception of the hedge). The Company's policies prohibit the use of
leveraged financial instruments. In addition, Reliant Energy Services, a
subsidiary of Resources, maintains a portfolio of Energy Derivatives to provide
price risk management services and for trading purposes (Trading Derivatives).
The Company uses value-at-risk and a sensitivity analysis method for
assessing the market risk of its derivatives.
56
<PAGE> 61
With respect to the Energy Derivatives (other than Trading Derivatives)
held by subsidiaries of the Company and Resources as of December 31, 1998, a
decrease of 10% in the market prices of natural gas and electric power from
year-end levels would decrease the fair value of these instruments by
approximately $3 million. As of December 31, 1997, a decrease of 10% in the
prices of natural gas would have resulted in a loss of $7 million in fair values
of the Energy Derivatives (other than for trading purposes).
The above analysis of the Energy Derivatives utilized for hedging purposes
does not include the favorable impact that the same hypothetical price movement
would have on the Company's and its subsidiaries' physical purchases and sales
of natural gas and electric power to which the hedges relate. The portfolio of
Energy Derivatives held for hedging purposes is no greater than the notional
quantity of the expected or committed transaction volume of physical commodities
with equal and opposite commodity price risk for the same time periods.
Furthermore, the Energy Derivative portfolio is managed to complement the
physical transaction portfolio, reducing overall risks within limits. Therefore,
the adverse impact to the fair value of the portfolio of Energy Derivatives held
for hedging purposes associated with the hypothetical changes in commodity
prices referenced above would be offset by a favorable impact on the underlying
hedged physical transactions, assuming (i) the Energy Derivatives are not closed
out in advance of their expected term, (ii) the Energy Derivatives continue to
function effectively as hedges of the underlying risk and (iii) as applicable,
anticipated transactions occur as expected.
The disclosure with respect to the Energy Derivatives relies on the
assumption that the contracts will exist parallel to the underlying physical
transactions. If the underlying transactions or positions are liquidated prior
to the maturity of the Energy Derivatives, a loss on the financial instruments
may occur, or the options might be worthless as determined by the prevailing
market value on their termination or maturity date, whichever comes first.
With respect to the Trading Derivatives held by Reliant Energy Services,
consisting of natural gas, electric power, crude oil and refined products,
physical forwards, swaps, options and exchange-traded futures, this subsidiary
is exposed to losses in fair value due to changes in the price and volatility of
the underlying derivatives. During the year ended December 31, 1998 and 1997,
the highest, lowest and average monthly value-at-risk in the Trading Derivative
portfolio was less than $5 million at a 95% confidence level and for a holding
period of one business day. The Company uses the variance/covariance method for
calculating the value-at-risk and includes the delta approximation for options
positions.
The Company has established a Corporate Risk Oversight Committee comprised
of corporate and business segment officers that oversees all corporate price and
credit risk activities, including derivative trading activities discussed above.
The committee's duties are to establish the Company's policies and to monitor
and ensure compliance with risk management policies and procedures and the
trading limits established by the Company's board of directors.
57
<PAGE> 62
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA OF THE COMPANY.
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED INCOME
(THOUSANDS OF DOLLARS EXCEPT PER SHARE AMOUNTS)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------------------
1998 1997 1996
------------ ------------ ------------
<S> <C> <C> <C>
REVENUES:
Electric Operations ..................................... $ 4,350,275 $ 4,251,243 $ 4,025,027
Natural Gas Distribution ................................ 1,812,676 892,569
Interstate Pipelines .................................... 282,496 108,333
Wholesale Energy ........................................ 4,456,158 1,364,658
International ........................................... 258,945 92,028 62,059
Other ................................................... 748,922 339,731 8,191
Eliminations ............................................ (421,008) (170,337)
------------ ------------ ------------
Total .......................................... 11,488,464 6,878,225 4,095,277
------------ ------------ ------------
EXPENSES:
Fuel and cost of gas sold ............................... 4,784,704 2,852,375 1,043,618
Purchased power ......................................... 2,215,049 698,823 322,263
Operation and maintenance ............................... 1,660,531 1,216,126 942,604
Taxes other than income taxes ........................... 494,175 394,526 246,288
Depreciation and amortization ........................... 856,617 651,875 550,038
------------ ------------ ------------
Total .......................................... 10,011,076 5,813,725 3,104,811
------------ ------------ ------------
OPERATING INCOME ............................................ 1,477,388 1,064,500 990,466
------------ ------------ ------------
OTHER INCOME (EXPENSE):
Unrealized loss on ACES ................................. (1,176,211) (121,402)
Litigation settlements .................................. (95,000)
Time Warner dividend income ............................. 41,250 41,340 41,610
Interest income -- IRS refund ........................... 981 56,269
Other -- net ............................................ 23,870 10,347 (2,022)
------------ ------------ ------------
Total .......................................... (1,110,110) (13,446) (55,412)
------------ ------------ ------------
INTEREST AND OTHER CHARGES:
Interest on long-term debt .............................. 416,138 320,845 276,242
Other interest .......................................... 97,767 77,112 33,738
Distribution on trust securities ........................ 29,201 26,230
Allowance for borrowed funds used during construction ... (4,304) (2,872) (2,598)
Preferred dividends of subsidiary ....................... 2,255 22,563
------------ ------------ ------------
Total .......................................... 538,802 423,570 329,945
------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES AND PREFERRED DIVIDENDS ... (171,524) 627,484 605,109
INCOME TAX EXPENSE (BENEFIT) ................................ (30,432) 206,374 200,165
------------ ------------ ------------
NET INCOME (LOSS) ........................................... (141,092) 421,110 404,944
PREFERRED DIVIDENDS ......................................... 390 162
------------ ------------ ------------
NET INCOME (LOSS) AVAILABLE FOR COMMON STOCK ................ $ (141,482) $ 420,948 $ 404,944
------------ ------------ ------------
BASIC AND DILUTED EARNINGS (LOSS) PER SHARE ................. $ (0.50) $ 1.66 $ 1.66
============ ============ ============
</TABLE>
See Notes to the Company's Consolidated Financial Statements
58
<PAGE> 63
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED RETAINED EARNINGS
AND COMPREHENSIVE INCOME
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------------------------------------------------------------
1998 1997 1996
-------------------------- -------------------------- --------------------------
<S> <C> <C> <C> <C> <C> <C>
RETAINED EARNINGS:
Balance at beginning of year ........ $ 2,013,055 $ 1,997,490 $ 1,953,672
Net income (loss) available for
common stock ...................... (141,482) $ (141,482) 420,948 $ 420,948 404,944 $ 404,944
----------- ----------- -----------
Total ............................. 1,871,573 2,418,438 2,358,616
Common stock dividends:
$1.50 per share (1996-1998) ....... (426,492) (405,383) (361,126)
----------- ----------- -----------
Balance at end of year .............. $ 1,445,081 $ 2,013,055 $ 1,997,490
=========== =========== ===========
ACCUMULATED OTHER COMPREHENSIVE INCOME
(LOSS), NET OF TAX:
Balance at beginning of year ........ $ (6,455) $ (363)
Foreign currency translation
adjustments ....................... (32,790) (32,790) (458) (458) $ (363) (363)
Unrealized loss on available for sale
securities (net of tax) ........... (10,370) (10,370) (5,634) (5,634)
----------- ----------- -----------
Balance at end of year .............. $ (49,615) $ (6,455) $ (363)
=========== =========== ===========
----------- ----------- -----------
COMPREHENSIVE INCOME (LOSS) ............ $ (184,642) $ 414,856 $ 404,581
=========== =========== ===========
</TABLE>
See Notes to the Company's Consolidated Financial Statements
59
<PAGE> 64
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF DOLLARS)
ASSETS
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------------
1998 1997
----------- -----------
<S> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents ...................................... $ 29,673 $ 51,712
Accounts receivable - net ...................................... 726,377 962,974
Accrued unbilled revenues ...................................... 175,515 205,860
Time Warner dividends receivable ............................... 10,313 10,313
Fuel stock and petroleum products .............................. 211,750 88,819
Materials and supplies, at average cost ........................ 171,998 156,160
Price risk management assets ................................... 265,203
Prepayments and other current assets ........................... 78,342 93,903
----------- -----------
Total current assets ......................................... 1,669,171 1,569,741
----------- -----------
PROPERTY, PLANT AND EQUIPMENT -- AT COST:
Electric ....................................................... 13,969,302 13,249,855
Natural gas .................................................... 1,686,159 1,500,278
Interstate pipelines ........................................... 1,302,829 1,258,087
Other property ................................................. 72,299 42,321
----------- -----------
Total ........................................................ 17,030,589 16,050,541
Less accumulated depreciation and amortization ................. 5,499,448 4,770,179
----------- -----------
Property, plant and equipment - net .......................... 11,531,141 11,280,362
----------- -----------
OTHER ASSETS:
Goodwill - net ................................................. 2,098,890 2,026,395
Equity investments and advances to unconsolidated subsidiaries . 1,051,600 704,102
Investment in Time Warner securities ........................... 990,000 990,000
Deferred plant costs - net ..................................... 535,787 561,569
Deferred debits ................................................ 514,930 478,686
Unamortized debt expense and premium on reacquired debt ........ 208,350 202,453
Regulatory tax asset - net ..................................... 418,339 356,509
Fuel-related debits ............................................ 65,278 197,304
Recoverable project costs - net ................................ 55,036 78,485
----------- -----------
Total other assets ........................................... 5,938,210 5,595,503
----------- -----------
Total ...................................................... $19,138,522 $18,445,606
=========== ===========
</TABLE>
See Notes to the Company's Consolidated Financial Statements
60
<PAGE> 65
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF DOLLARS)
CAPITALIZATION AND LIABILITIES
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------------
1998 1997
----------- -----------
<S> <C> <C>
CURRENT LIABILITIES:
Notes payable .............................................................. $ 1,812,739 $ 2,124,956
Accounts payable ........................................................... 807,977 879,612
Taxes accrued .............................................................. 252,581 240,739
Interest accrued ........................................................... 115,201 109,901
Dividends declared ......................................................... 111,058 110,716
Customer deposits .......................................................... 77,937 82,437
Price risk management liabilities .......................................... 227,652
Current portion of long-term debt .......................................... 397,454 251,169
Other ...................................................................... 268,343 224,435
----------- -----------
Total current liabilities ................................................ 4,070,942 4,023,965
----------- -----------
DEFERRED CREDITS:
Accumulated deferred income taxes .......................................... 2,364,036 2,792,781
Benefit obligations ........................................................ 378,747 397,586
Unamortized investment tax credit .......................................... 328,949 349,072
Fuel-related credits ....................................................... 88,639 75,956
Other ...................................................................... 442,361 329,514
----------- -----------
Total deferred credits ................................................... 3,602,732 3,944,909
----------- -----------
CAPITALIZATION (STATEMENTS ON FOLLOWING PAGES):
Long-term debt ............................................................. 6,800,748 5,218,015
Company/Resources obligated mandatorily redeemable preferred securities of
subsidiary trusts holding solely junior subordinated debentures of
Company/Resources ........................................................ 342,232 362,172
Preference stock, none outstanding
Cumulative preferred stock, not subject to mandatory redemption ............ 9,740 9,740
Common stock equity ........................................................ 4,312,128 4,886,805
----------- -----------
Total capitalization ..................................................... 11,464,848 10,476,732
----------- -----------
COMMITMENTS AND CONTINGENCIES (NOTE 12)
Total .................................................................. $19,138,522 $18,445,606
=========== ===========
</TABLE>
See Notes to the Company's Consolidated Financial Statements
61
<PAGE> 66
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
DECEMBER 31,
----------------------------
1998 1997
----------- -----------
<S> <C> <C>
Long-Term Debt:
7% Automatic common exchange securities, due 2000 ... $ 2,349,997 $ 1,173,786
----------- -----------
Debentures:
9 3/8% series, due 2001 ........................... 250,000 250,000
7 7/8% series, due 2002 ........................... 100,000 100,000
8.9% series, due 2006 ............................. 163,357 165,055
6% convertible subordinated, due 2012 ............. 104,617 107,180
10% series, due 2019 .............................. 47,562 47,773
6 1/2% series, due 2008 ........................... 300,000
6 3/8% series, due 2003 ........................... 500,000
Unamortized premium ............................... 17,046
Unamortized discount .............................. (532) (717)
----------- -----------
Total debentures ................................ 1,482,050 669,291
----------- -----------
First Mortgage Bonds:
9.15% series, due 2021 ............................ 102,442 102,442
8 3/4% series, due 2022 ........................... 62,275 62,275
7 3/4% series, due 2023 ........................... 250,000 250,000
7 1/2% series, due 2023 ........................... 200,000 200,000
4.90% pollution control series, due 2003 .......... 16,600 16,600
7% pollution control series, due 2008 ............. 19,200 19,200
6 3/8% pollution control series, due 2012 ......... 33,470 33,470
6 3/8% pollution control series, due 2012 ......... 12,100 12,100
8 1/4% pollution control series, due 2015 ......... 90,000
5.80% pollution control series, due 2015 .......... 91,945 91,945
7 3/4% pollution control series, due 2015 ......... 68,700
5.80% pollution control series, due 2015 .......... 58,905 58,905
6.70% pollution control series, due 2017 .......... 43,820 43,820
5.60% pollution control series, due 2017 .......... 83,565 83,565
7.20% pollution control series, due 2018 .......... 75,000 75,000
7.20% pollution control series, due 2018 .......... 100,000 100,000
7 7/8 % pollution control series, due 2019 ........ 29,685
7.70% pollution control series, due 2019 .......... 75,000
8 1/4% pollution control series, due 2019 ......... 100,000
8.10% pollution control series, due 2019 .......... 100,000
7 5/8% pollution control series, due 2019 ......... 100,000 100,000
7 1/8% pollution control series, due 2019 ......... 100,000 100,000
7.60% pollution control series, due 2019 .......... 70,315 70,315
6.70% pollution control series, due 2027 .......... 56,095 56,095
6.10% medium-term notes, series C, due 2000 ....... 150,000 150,000
8.15% medium-term notes, series B, due 2002 ....... 100,000 100,000
6.50% medium-term notes, series C, due 2003 ....... 150,000 150,000
9.85% medium-term notes, due 1999 ................. 25,400 25,400
9.80% medium-term notes, due 1999 ................. 145,100 145,100
Unamortized discount .............................. (9,948) (14,158)
----------- -----------
Total first mortgage bonds ...................... 2,036,284 2,495,459
----------- -----------
</TABLE>
(continued on next page)
62
<PAGE> 67
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION -- (CONTINUED)
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
DECEMBER 31,
----------------------------
1998 1997
----------- -----------
<S> <C> <C>
Pollution Control Revenue Bonds:
Gulf Coast 1980-T series, floating rate, due 1998 ......................... $ 5,000
4.90% BRA 1998D, due 2015 ............................................. $ 68,700
5.05% BRA 1997, due 2018 .............................................. 50,000 50,000
5.125% BRA 1998A, due 2019 ............................................ 100,000
5.125% BRA 1998C, due 2019 ............................................ 100,000
5.125% BRA 1998B, due 2020 ............................................ 90,000
5.125% MCND 1997, due 2028 ............................................ 68,000 68,000
5.25% MCND 1998A, due 2029 ............................................ 29,685
5.15% MCND 1998B, due 2029 ............................................ 75,000
----------- -----------
Total pollution control revenue bonds ................................... 581,385 123,000
----------- -----------
Medium-Term Notes:
Series A, 9.30%-9.39%, due 1999-2000 ...................................... 23,063 24,838
Series B, 8.43%-9.23%, due 1999-2001 ...................................... 154,626 236,367
----------- -----------
Total medium-term notes ................................................. 177,689 261,205
----------- -----------
Capitalized lease obligations, discount rates of 5.2%-11.7%, due 1999-2018 .. 14,883 16,166
Notes payable ............................................................... 555,914 730,277
----------- -----------
Subtotal .................................................................. 570,797 746,443
----------- -----------
Total ................................................................... 7,198,202 5,469,184
Current maturities ...................................................... (397,454) (251,169)
----------- -----------
Total long-term debt .................................................... 6,800,748 5,218,015
----------- -----------
Company/Resources obligated mandatorily redeemable preferred securities of
subsidiary trusts holding solely junior subordinated debentures of
Company/Resources:
8.125% Trust Preferred Securities, Series A ................................. 250,000 250,000
8.257% Trust Capital Securities, Series B ................................... 100,000 100,000
6 1/4% Convertible Trust Originated Preferred Securities .................... 1,178 21,730
Unamortized Issuance Costs .................................................. (8,946) (9,558)
----------- -----------
Total Company/Resources obligated mandatorily redeemable preferred
securities of subsidiary trusts holding solely junior subordinated
debentures of Company/Resources-net ................................... 342,232 362,172
----------- -----------
Cumulative Preferred Stock, no par; authorized, 10,000,000 shares;
outstanding 97,397 shares each at December 31, 1998 and 1997, (entitled
upon involuntary liquidation to $100 per share):
Not subject to mandatory redemption:
$4.00 series, 97,397 shares ............................................... 9,740 9,740
----------- -----------
Preference Stock, no par; authorized, 10,000,000 shares; none outstanding......
</TABLE>
(continued on next page)
63
<PAGE> 68
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION -- (CONTINUED)
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------
1998 1997
------------ ------------
<S> <C> <C>
Common Stock Equity:
Common stock, no par; authorized, 700,000,000 shares; issued, 296,271,063
and 295,357,276 shares at December 31, 1998 and 1997, respectively ....... $ 3,136,826 $ 3,112,098
Treasury stock, at cost; 102,805 and 93,459 shares at December 31, 1998
and 1997, respectively ................................................... (2,384) (2,066)
Unearned ESOP shares, 11,674,063 and 12,388,551 shares at December 31,
1998 and 1997, respectively .............................................. (217,780) (229,827)
Retained earnings .......................................................... 1,445,081 2,013,055
Accumulated other comprehensive loss ....................................... (49,615) (6,455)
------------ ------------
Total common stock equity .............................................. 4,312,128 4,886,805
------------ ------------
Total capitalization ................................................. $ 11,464,848 $ 10,476,732
============ ============
</TABLE>
See Notes to the Company's Consolidated Financial Statements
64
<PAGE> 69
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED CASH FLOWS
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
---------------------------------------------
1998 1997 1996
----------- ----------- -----------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) available for common stock .................... $ (141,482) $ 420,948 $ 404,944
Adjustments to reconcile net income (loss) to net cash
provided by operating activities:
Depreciation and amortization ................................. 856,617 651,875 550,038
Amortization of nuclear fuel .................................. 25,529 28,237 33,875
Deferred income taxes ......................................... (423,904) 35,523 54,098
Investment tax credit ......................................... (20,123) (19,777) (18,404)
Unrealized loss on ACES ....................................... 1,176,211 121,402
Contribution of marketable equity securities to charitable
trust ....................................................... 19,463
Undistributed earnings of equity investments in
unconsolidated subsidiaries ................................. (27,350) (3,142) (15,290)
Fuel cost over (under) recovery ............................... (22,545) (212,683) (137,362)
Changes in other assets and liabilities:
Accounts receivable - net ................................... 266,938 (436,580) (15,478)
Fuel surcharge .............................................. 94,912 128,864
Inventory ................................................... (121,793) 55,111 21,624
Other current assets ........................................ (15,705) 6,966 (306)
Accounts payable ............................................ (92,652) 191,840 21,674
Interest and taxes accrued .................................. 7,044 18,425 4,413
Other current liabilities ................................... 33,078 2,985 (4,135)
Net price risk management assets ............................ (29,857)
Other - net ................................................. (139,559) 101,302 14,629
----------- ----------- -----------
Net cash provided by operating activities ................ 1,425,359 1,110,759 914,320
----------- ----------- -----------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (including allowance for borrowed funds
used during construction) ..................................... (743,455) (328,724) (317,532)
Purchase of Resources, net of cash acquired ..................... (1,422,672)
Non-rate regulated electric power project expenditures
(including capitalized interest) .............................. (292,398)
Sale of equity investments in foreign electric system projects .. 242,744
Equity investment and advances to unconsolidated subsidiaries ... (445,042) (234,852) (495,379)
Sale of Time Warner securities .................................. 25,043
Other-net ....................................................... 8,375 (20,248) (19,989)
----------- ----------- -----------
Net cash used in investing activities .................... $(1,229,776) $(1,981,453) $ (832,900)
----------- ----------- -----------
</TABLE>
(continued on next page)
65
<PAGE> 70
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED CASH FLOWS - (CONTINUED)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
---------------------------------------------
1998 1997 1996
----------- ----------- -----------
<S> <C> <C> <C>
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from sale of ACES - net .............................. $ 1,020,777
Proceeds from sale of Company obligated mandatorily
redeemable trust preferred securities of subsidiary trusts
holding solely subordinated debentures of Company - net ..... 340,785
Purchase of treasury stock .................................... $ (361,196)
Payment of matured bonds ...................................... $ (226,000) (277,000) (150,000)
Proceeds from issuance of debentures .......................... 812,849
Proceeds from issuance of pollution control revenue bonds ..... 454,258 115,739
Redemption of preferred stock ................................. (153,628) (271,400)
Payment of common stock dividends ............................. (426,265) (405,288) (361,126)
Increase/(decrease) in notes payable - net .................... (348,044) 587,791 1,331,572
Extinguishment of long-term debt .............................. (471,287) (303,893) (285,263)
Conversion of convertible securities .......................... (10,450) (9,504)
Other - net ................................................... (2,683) (1,374) 12,215
----------- ----------- -----------
Net cash provided by (used in) financing activities ...... (217,622) 914,405 (85,198)
----------- ----------- -----------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS ............. (22,039) 43,711 (3,778)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD ................. 51,712 8,001 11,779
----------- ----------- -----------
CASH AND CASH EQUIVALENTS AT END OF PERIOD ....................... $ 29,673 $ 51,712 $ 8,001
=========== =========== ===========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash Payments:
Interest (net of amounts capitalized) ......................... $ 511,165 $ 437,952 $ 311,792
Income taxes .................................................. 484,376 171,539 139,898
</TABLE>
The aggregate consideration paid in August 1997 to former stockholders of
Resources in connection with the Merger consisted of $1.4 billion in cash and
47.8 million shares of the Company's common stock valued at approximately $1.0
billion. The overall transaction was valued at $4.0 billion consisting of $2.4
billion for Former Resources' common stock and common stock equivalents and $1.6
billion of Former Resources' debt.
See Notes to the Company's Consolidated Financial Statements
66
<PAGE> 71
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
FOR THE THREE YEARS ENDED DECEMBER 31, 1998
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) Nature of Operations.
Houston Industries Incorporated d/b/a Reliant Energy, Incorporated
(Company), together with its subsidiaries, is a diversified international energy
services company. The Company is both an electric utility company and a utility
holding company. The Company's wholly owned subsidiary, Reliant Energy Resources
Corp. (Resources), operates in various phases of the natural gas industry,
including distribution, transmission, marketing and gathering.
Effective January 1, 1998, the Company reconfigured its financial reporting
segments to include the following: Electric Operations, Natural Gas
Distribution, Interstate Pipeline, Wholesale Energy Marketing and Generation
(Wholesale Energy), International and Corporate. Electric Operations includes
operations of Reliant Energy HL&P. Natural Gas Distribution consists of natural
gas sales to, and natural gas transportation for, residential commercial and
industrial customers. Interstate Pipeline includes the interstate natural gas
pipeline operations of Resources. Wholesale Energy is engaged in the
acquisition, development and operation of non-rate regulated power generation
facilities as well as the wholesale energy marketing and natural gas gathering
businesses. International participates in the development and acquisition of
foreign independent power projects and the privatization of foreign generation
and distribution facilities. Corporate includes the Company's unregulated retail
electric services business, certain real estate holdings of the Company and
corporate costs.
In February 1999, the Company began doing business as Reliant Energy,
Incorporated. On May 5, 1999, the Company's shareholders will vote on a proposal
to amend the Restated Articles of Incorporation to change its name to "Reliant
Energy, Incorporated."
(b) Resources Acquisition.
On August 6, 1997 (Acquisition Date), the former parent corporation (Former
Parent) of the Company merged with and into the Company, and NorAm Energy
Corp., a natural gas gathering, transmission, marketing and distribution company
(Former NorAm), merged with and into Resources. Effective upon the mergers
(collectively, the Merger), each outstanding share of common stock of Former
Parent was converted into one share of common stock (including associated
preference stock purchase rights) of the Company, and each outstanding share of
common stock of Former NorAm was converted into the right to receive $16.3051
cash or 0.74963 shares of common stock of the Company. The aggregate
consideration paid to Former NorAm stockholders in connection with the Merger
consisted of $1.4 billion in cash and 47.8 million shares of the Company's
common stock valued at approximately $1.0 billion. The overall transaction was
valued at $4.0 billion consisting of $2.4 billion for Former NorAm's common
stock and common stock equivalents and $1.6 billion of Former NorAm debt ($1.3
billion of which was long-term debt).
The Company recorded the acquisition under the purchase method of
accounting with assets and liabilities of Former NorAm reflected at their
estimated fair values as of the Acquisition Date. The excess of the purchase
price over the fair value of net assets acquired was initially estimated at $2
billion. In 1998, the fair value estimates of the assets acquired and
liabilities assumed were finalized resulting in a $78 million increase in
goodwill. The Company has recorded the excess of the acquisition cost over the
fair value of the net assets acquired as goodwill and is amortizing this amount
over 40 years. The Company's fair value adjustments included increases in
property, plant and equipment, long-term debt, unrecognized pension and
postretirement benefits liabilities and related deferred taxes.
67
<PAGE> 72
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The Company's results of operations incorporate Resources' results of
operations only for the period beginning on the Acquisition Date. The following
table presents certain actual financial information for the year ended December
31, 1998 and unaudited pro forma information for the years ended December 31,
1997 and 1996, as if the Merger had occurred on January 1, 1997 and 1996,
respectively.
ACTUAL AND PRO FORMA COMBINED RESULTS OF OPERATIONS
(IN MILLIONS, EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------------------------------------
1998 1997 1996
------------ ------------------------- ------------ -------------
ACTUAL ACTUAL PRO FORMA ACTUAL PRO FORMA
------------ ------------ ------------ ------------ -------------
(UNAUDITED) (UNAUDITED)
<S> <C> <C> <C> <C> <C>
Revenues........................................... $ 11,488 $ 6,878 $ 10,191 $ 4,095 $ 8,884
Net Income (Loss) Available for Common Stock(1).... $ (142) $ 421 $ 437 $ 405 $ 426
Basic and Diluted Earnings (Loss) Per Share(1)..... $ (.50) $ 1.66 $ 1.55 $ 1.66 $ 1.46
</TABLE>
- ---------
(1) Net income (loss) available for common stock for 1998 and 1997 are
negatively impacted by $764 million and $79 million ($2.69 and $0.31 per
share) respectively, related to the unrealized loss on the Company's 7%
Automatic Common Exchange Securities (ACES).
These and other pro forma results appearing in this Form 10-K are based on
assumptions deemed appropriate by the Company's management, have been prepared
for informational purposes only and are not necessarily indicative of the
combined results that would have resulted had the Merger occurred at the
beginning of the 1996 and 1997 reporting periods presented. Purchase-related
adjustments to results of operations include amortization of goodwill and the
effects on depreciation, amortization, interest expense and deferred income
taxes of the assessed fair value of certain Resources assets and liabilities.
(c) Regulatory Assets and Other Long-Lived Assets.
The Company and certain subsidiaries of Resources apply the accounting
policies established in SFAS No. 71, "Accounting for the Effects of Certain
Types of Regulation" (SFAS No. 71), to the accounts of Electric Operations,
Natural Gas Distribution and the Interstate Pipeline operations of a subsidiary
of Resources. In general, SFAS No. 71 permits a company with cost-based rates to
defer certain costs that would otherwise be expensed to the extent that the rate
regulated company is recovering or expects to recover such costs in rates
charged to its customers.
The following is a list of regulatory assets/liabilities reflected on the
Company's Consolidated Balance Sheet as of December 31, 1998, detailed by
Electric Operations and other segments.
<TABLE>
<CAPTION>
ELECTRIC TOTAL
OPERATIONS OTHER COMPANY
---------- ----- -------
(MILLIONS OF DOLLARS)
<S> <C> <C> <C>
Deferred plant costs-- net............................................ $ 536 $ $ 536
Recoverable project costs-- net....................................... 55 55
Regulatory tax asset-- net............................................ 418 418
Unamortized loss on reacquired debt................................... 140 140
Fuel-related debits/credits-- net..................................... (15) (15)
Other deferred debits................................................. 54 12 66
--------- -------- --------
Total....................................................... $ 1,188 $ 12 $ 1,200
--------- -------- --------
</TABLE>
If, as a result of changes in regulation or competition, the Company's and
Resources' ability to recover these assets and liabilities would not be assured,
then pursuant to SFAS No. 101, "Accounting for the Discontinuation of
Application of SFAS No. 71" (SFAS No. 101) and SFAS No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived
68
<PAGE> 73
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Assets to Be Disposed Of" (SFAS No. 121), the Company and Resources would be
required to write off or write down such regulatory assets and liabilities,
unless some form of transition cost recovery continues through rates established
and collected for their remaining regulated operations. In addition, the Company
and Resources would be required to determine any impairment to the carrying
costs of deregulated plant and inventory assets. In order to reduce exposure to
potentially stranded costs related to generation assets, Electric Operations
redirected $195 million of depreciation in 1998 from transmission, distribution
and general plant assets to generation assets. Such redirection is in accordance
with the Company's transition to competition plan (Transition Plan) described in
Note 1(f). If Electric Operations was required to apply SFAS No. 101 to the
generation portion of its business only, the cumulative amount of redirected
depreciation of $195 million would become a regulatory asset of the transmission
and distribution portion of its business.
Effective January 1, 1996, the Company and Resources adopted SFAS No. 121.
SFAS No. 121 requires that long-lived assets and certain identifiable
intangibles to be held and used or disposed of by an entity be reviewed for
impairment whenever events or changes in circumstances indicate that the
carrying amount of an asset may not be recoverable. Adoption of the standard did
not result in a write-down of the carrying amount of any asset on the books of
the Company or Resources.
In July 1997, the Emerging Issues Task Force (EITF) of the Financial
Accounting Standards Board reached a consensus on Issue No. 97-4, "Deregulation
of the Pricing of Electricity -- Issues Related to the Application of FASB
Statements No. 71, Accounting for the Effects of Certain Types of Regulation,
and No. 101, Regulated Enterprises -- Accounting for the Discontinuation of
Application of FASB Statement No. 71" (EITF 97-4). EITF 97-4 concluded that the
application of SFAS No. 71 to a segment which is subject to a deregulation plan
should cease when the legislation and enabling rate order contain sufficient
detail for the utility to reasonably determine how the plan will affect the
segment to be deregulated. In addition, EITF 97-4 requires the regulatory assets
and liabilities to be allocated to the applicable portion of the electric
utility from which the source of the regulated cash flows will be derived. As a
part of the Transition Plan, the Company has agreed to support future
legislation providing for retail customer choice and other provisions consistent
with those in the 1997 proposed Texas legislation. At this time, the Company is
unable to make any predictions as to the details of legislation being considered
by the Texas legislature or the likelihood that such legislation will ultimately
be enacted. Although the Company has determined that no impairment loss or
write-offs of regulatory assets or carrying costs of plant and inventory assets
need to be recognized for applicable assets of Electric Operations as of
December 31, 1998, this conclusion may change in the future (i) as competition
influences wholesale and retail pricing in the electric utility industry, (ii)
depending on regulatory action, if any and (iii) depending on legislation, if
any, that is passed.
(d) Principles of Consolidation.
The consolidated financial statements include the accounts of the Company
and its wholly owned and majority owned subsidiaries including, effective as of
the Acquisition Date, the accounts of Resources and its wholly owned and
majority owned subsidiaries.
Investments in entities in which the Company or its subsidiaries have an
ownership interest between 20% and 50% or are able to exercise significant
influence are accounted for using the equity method. For additional information
regarding investments recorded using the equity method or the cost method of
accounting, see Note 5.
All significant intercompany transactions and balances are eliminated in
consolidation.
(e) Property, Plant and Equipment and Goodwill.
Property, plant and equipment are stated at original cost of the acquirer.
Repair and maintenance costs are expensed. Depreciation is computed using the
straight-line method.
69
<PAGE> 74
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Goodwill is being amortized on a straight-line basis over 30 to 40 years.
The Company had $76.3 million and $21.6 million accumulated goodwill
amortization at December 31, 1998 and 1997, respectively. The Company will
periodically compare the carrying value of its goodwill to the anticipated
undiscounted future operating income from the businesses whose acquisition gave
rise to the goodwill and as of yet no impairment is indicated or expected.
(f) Depreciation and Amortization Expense.
The Company's consolidated depreciation expense for 1998 was $548 million
compared to $475 million for 1997 and $410 million for 1996.
In June 1998, the Public Utility Commission of Texas (Texas Utility
Commission) issued an order approving the Transition Plan filed by Electric
Operations in December 1997. In order to reduce Electric Operations' exposure to
potentially stranded costs related to generation assets, the Transition Plan
permits the redirection to generation assets of depreciation expense that
Electric Operations otherwise would apply to transmission, distribution and
general plant assets. In addition, the Transition Plan provides that all
earnings above a 9.844% overall annual rate of return on invested capital be
used to recover Electric Operations' investment in generation assets. Electric
Operations implemented the Transition Plan effective January 1, 1998 and
pursuant to its terms, recorded an aggregate of $194 million in additional
depreciation and $195 million in redirected depreciation in 1998.
The Company's depreciation and amortization expenses included $50 million
of additional depreciation relating to the South Texas Project Electric
Generating Station (South Texas Project) in both 1997 and 1996 and goodwill
amortization relating to the acquisition of Resources of $55 million in 1998 and
$22 million in 1997. For additional information regarding the operation of
goodwill in connection with the Merger, see Note 1(b) above. The depreciation
expense recorded for the South Texas Project was made pursuant to the terms of
the Company's 1995 rate case settlement (1995 Rate Case Settlement), which
permitted the Company to write down as much as $50 million per year of its
investment in the South Texas Project through December 31, 1999. These
write-downs are treated under the 1995 Rate Case Settlement as reasonable and
necessary expenses for purposes of any future earnings reviews or other
proceedings.
In 1998, 1997 and 1996, the Company, as permitted by the 1995 Rate Case
Settlement, also amortized $4 million, $66 million and $50 million (pre-tax),
respectively, of its $153 million investment in certain lignite reserves
associated with a canceled generating station. The Company's remaining
investment in the canceled generating station and certain lignite reserves will
be amortized fully no later than December 31, 2002.
(g) Deferred Plant Costs.
Under a "deferred accounting" plan authorized by the Texas Utility
Commission, Electric Operations was permitted for regulatory purposes to accrue
carrying costs in the form of allowance for funds used during construction
(AFUDC) on its investment in the South Texas Project and to defer and capitalize
depreciation and other operating costs on its investment after commercial
operation until such costs were reflected in rates. In addition, the Texas
Utility Commission authorized Electric Operations under a "qualified phase-in
plan" to capitalize allowable costs (including return) deferred for future
recovery as deferred charges.
In 1991, Electric Operations ceased all cost deferrals related to the South
Texas Project and began amortizing such amounts on a straight-line basis. The
accumulated deferrals for "deferred accounting" are being amortized over the
estimated depreciable life of the South Texas Project. The accumulated deferrals
for the "qualified phase-in plan" are being amortized over a ten-year phase-in
period that commenced in 1991. The amortization of all deferred plant costs
(which totaled $26 million for each of the years 1998, 1997 and 1996) is
included on the Company's Statements of Consolidated Income as depreciation and
amortization expense.
70
<PAGE> 75
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(h) Fuel Stock and Petroleum Products.
Gas inventory (primarily using the average cost method) was $96 million and
$72 million at December 31, 1998 and 1997, respectively. Coal and lignite
inventory balances (using last-in, first-out) were $24 million and $7 million,
respectively, at December 31, 1998 and $8 million and $6 million, respectively,
at December 31, 1997. Oil inventory balances, principally heating oil, were $85
million and $3 million at December 31, 1998 and 1997, respectively.
Heating oil is used in trading operations and are marked-to-market in
connection with the price risk management activities discussed in Note 2.
(i) Revenues.
The Company records electricity and natural gas sales under the full
accrual method, whereby unbilled electricity and natural gas sales are estimated
and recorded each month. International revenues include electricity sales of a
majority owned foreign electric utility, which are also recorded under the full
accrual method, and equity income (net of foreign taxes) in unconsolidated
investments of Reliant Energy International. In 1998, International's revenues
included the gain on the sale of an Argentine electric distribution system.
Included in other revenues are management fees and other sales and services,
which are recorded when earned.
Revenue eliminations of $421 million and $170 million for the years ended
December 31, 1998 and 1997, respectively, represent intersegment sales of
natural gas and transportation services. For the year ended December 31, 1998,
Interstate Pipeline had intersegment revenues of $156 million, Wholesale Energy
had intersegment sales of $167 million and Corporate had $98 million of
intersegment retail sales. For the five month period ended December 31, 1997,
Interstate Pipelines had intersegment revenues of $59 million, Wholesale Energy
had intersegment sales of $76 million and Corporate had $35 million of
intersegment retail sales.
(j) Earnings Per Common Share.
Effective December 31, 1997, the Company adopted SFAS No. 128, "Earnings
per Share" (SFAS No 128). This statement requires restatement of all prior
period earnings per share (EPS) data presented herein. SFAS No. 128 requires
dual presentation of basic and diluted EPS on the face of the Statements of
Consolidated Income and requires a reconciliation of the numerators and
denominators used in the basic and diluted earnings per share calculations.
The following table reconciles numerators and denominators of the Company's
basic and diluted earnings per share calculations:
71
<PAGE> 76
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
FOR THE YEAR ENDED DECEMBER 31,
-----------------------------------------
1998 1997 1996
---------- ---------- ----------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C>
Basic EPS Calculation:
Net Income (loss) ............................................... $ (141,092) $ 421,110 $ 404,944
Less: Preferred dividends ....................................... 390 162
---------- ---------- ----------
Net income (loss) available for common stock .................... $ (141,482) $ 420,948 $ 404,944
========== ========== ==========
Weighted average shares outstanding ............................. 284,095 253,599 244,443
Basic EPS:
Net Income (loss) ............................................... $ (.50) $ 1.66 $ 1.66
Less: Preferred dividends ....................................... -- -- --
---------- ---------- ----------
Net income (loss) available for common stock .................... $ (.50) $ 1.66 $ 1.66
========== ========== ==========
Diluted EPS Calculation:
Net Income (loss) ............................................... $ (141,092) $ 421,110 $ 404,944
Plus: Income impact of assumed conversions
Interest on 63% convertible debentures ...................... 668
---------- ---------- ----------
Net Income (loss) assuming dilution ............................. (141,092) 421,778 404,944
Less: Preferred dividends ....................................... 390 162
---------- ---------- ----------
Net income (loss) available for common stock assuming dilution .. $ (141,482) $ 421,616 $ 404,944
========== ========== ==========
Weighted average shares outstanding ............................. 284,095 253,599 244,443
Plus: Incremental shares from assumed conversions: (1)
Stock options ................................................ 89 33
63% convertible debentures .................................. 510
---------- ---------- ----------
Weighted average shares assuming dilution ....................... 284,095 254,198 244,476
========== ========== ==========
Diluted EPS:
Net Income (loss) ............................................... $ (.50) $ 1.66 $ 1.66
Less: Preferred dividends ....................................... -- -- --
---------- ---------- ----------
Net income (loss) available for common stock .................... $ (.50) $ 1.66 $ 1.66
========== ========== ==========
</TABLE>
(1) No assumed conversions were included in the computation of diluted earnings
per share for 1998 because additional shares outstanding would result in an
anti-dilutive per share amount. The computation of diluted EPS for 1998 excludes
492,000 shares of restricted stock and purchase options for 434,000 shares of
common stock which would be anti-dilutive if exercised.
(k) Statements of Consolidated Cash Flows.
For purposes of reporting cash flows, cash equivalents are considered to be
short-term, highly liquid investments readily convertible to cash.
(l) Derivative Financial Instruments (Risk Management).
For information regarding the Company's accounting for derivative financial
instruments associated with its subsidiaries' natural gas, electric power and
transportation risk management activities, see Note 2.
(m) Income Taxes.
The Company and its subsidiaries file a consolidated federal income tax
return. The Company follows a policy of comprehensive interperiod income tax
allocation. Investment tax credits were deferred and are being amortized over
the estimated lives of the related property. For additional information
regarding income taxes, see Note 11.
72
<PAGE> 77
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(n) Investments in Time Warner Securities.
The Company owns 11 million shares of non-publicly traded Time Warner
convertible preferred stock (TW Preferred). The TW Preferred is redeemable after
July 6, 2000, has an aggregate liquidation preference of $100 per share (plus
accrued and unpaid dividends), is entitled to annual dividends of $3.75 per
share until July 6, 1999, is currently convertible by the Company and after July
6, 1999 is exchangeable by Time Warner into approximately 45.8 million shares of
Time Warner common stock (TW Common). Each share of TW Preferred is entitled to
two votes (voting together with the holders of the TW Common as a single class).
The Company has accounted for its investment in TW Preferred under the cost
method at a value of $990 million on the Company's Consolidated Balance Sheets.
Dividends on these securities are recognized as income at the time they are
earned. The Company recorded pre-tax dividend income with respect to the Time
Warner securities of $41.3 million in 1998 and 1997 and $41.6 million in 1996.
To monetize its investment in the TW Preferred, the Company sold in July
1997, 22.9 million of ACES. At maturity in July 2000, the principal amount of
the ACES will be mandatorily exchangeable by the Company into either (i) a
number of shares of TW Common based on an exchange rate or (ii) cash having an
equal value. Subject to adjustments that may result from certain dilution
events, the exchange rate for each ACES is determined as follows: (i) 1.6528
shares of TW Common if the price of TW Common at maturity (Maturity Price) is at
least $27.7922 per share, (ii) a fractional share of TW Common such that the
fractional share will have a value equal to $22.96875 if the Maturity Price is
less than $27.7922 but greater than $22.96875 and (iii) one share of TW Common
if the Maturity Price is not more than $22.96875. The closing price of TW Common
was $62.062 per share on December 31, 1998.
Prior to maturity, the Company has the option of redeeming the ACES if (i)
changes in federal tax regulations require recognition of a taxable gain on the
Company's TW Preferred and (ii) the Company could defer such gain by redeeming
the ACES. The redemption price is 105% of the closing sales price of the ACES as
determined over a period prior to the redemption notice. The redemption price
may be paid in cash or in shares of TW Common or a combination of the two.
As a result of the issuance of the ACES, a portion of the increase in the
market value above $27.7922 per share of TW Common results in non-cash,
unrealized accounting losses to the Company for the ACES, pending the conversion
of the Company's TW Preferred into TW Common. For example, prior to the
conversion, when the market price of TW Common increases above $27.7922, the
Company records in Other Income (Expense) an unrealized, non-cash accounting
loss for the ACES equal to (i) the aggregate amount of such increase as
applicable to all ACES multiplied by (ii) 0.8264. In accordance with generally
accepted accounting principles, this accounting loss (which reflects the
unrealized increase in the Company's indebtedness with respect to the ACES) may
not be offset by accounting recognition of the increase in the market value of
the TW Common that underlies the TW Preferred. Upon conversion of the TW
Preferred (anticipated to occur in July 1999), the Company will begin recording
future unrealized net changes in the market prices of the TW Common and the ACES
as a component of common stock equity and other comprehensive income.
As of December 31, 1998 and 1997, the market price of TW Common was $62.062
and $31.00 per share, respectively. Accordingly, the Company recognized an
increase of $1.2 billion in 1998 and $121 million in 1997 in the unrealized
liability relating to its ACES indebtedness (which resulted in an after-tax
earnings reduction of $764 million or $2.69 basic earnings per share and $79
million or $.31 basic earnings per share, respectively). The Company believes
that the cumulative unrealized loss for the ACES of approximately $1.3 billion
is more than economically hedged by the approximately $1.8 billion unrecorded
unrealized gain at December 31, 1998 relating to the increase in the fair value
of the TW Common underlying the investment in TW Preferred since the date of its
acquisition. Any gain related to the increase in fair value of TW Common would
be recognized as a component of net income upon the sale of the TW Preferred or
the shares of TW Common into which such TW Preferred is
73
<PAGE> 78
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
converted. As of March 11, 1999, the price of TW Common was $70.75 per share
which would have resulted in the Company recognizing an additional increase of
$329 million in the unrealized liability relating to its ACES indebtedness. The
related unrecorded unrealized gain as of March 11, 1999 would have been computed
as an additional $398 million.
(o) Investment in Other Debt and Equity Securities.
The securities held in the Company's nuclear decommissioning trust are
classified as "available-for-sale" and, in accordance with SFAS No. 115,
"Accounting for Certain Investments in Debt and Equity Securities" (SFAS No.
115), are reported at estimated fair value of $119.1 million as of December 31,
1998 and $92.9 million as of December 31, 1997 on the Company's Consolidated
Balance Sheets under deferred debits. The liability for nuclear decommissioning
is reported on the Company's Consolidated Balance Sheets under deferred credits.
Any unrealized gains or losses are accounted for in accordance with SFAS No. 71
as a regulatory asset/liability and reported on the Company's Consolidated
Balance Sheets as a deferred debit/credit.
The Company, through, Resources, holds certain equity securities classified
as "available-for-sale" and in accordance with SFAS No. 115, "Accounting for
Certain Investments in Debt and Equity Securities," reports such investments at
estimated fair value on the Company's Consolidated Balance Sheets as deferred
debits and any unrealized gain or loss, net of tax, as a separate component of
stockholders' equity and other comprehensive income. At December 31, 1998 and
1997, the accumulated unrealized loss, net of tax, relating to these equity
securities was approximately $16.0 million and $5.6 million.
(p) Foreign Currency Adjustments
International assets and liabilities where the local currency is the
functional currency, have been translated into U.S. dollars using the exchange
rate at the balance sheet date. Revenues, expenses, gains, and losses have been
translated using the weighted average exchange rate for each month prevailing
during the periods reported. Cumulative adjustments resulting from translation
have been recorded in stockholders' equity and other comprehensive income. When
the U.S. dollar is the functional currency, the financial statements of
International are remeasured in U.S. dollars using historical exchange rates for
non-monetary accounts and the current rate at the respective balance sheet date
and the weighted average exchange rate for all other balance sheet and income
statement accounts, respectively. All exchange gains and losses from
remeasurement and foreign currency transactions are included in consolidated net
income. However, fluctuations in foreign currency exchange rates relative to the
U.S. dollar can have an impact on the reported equity earnings of the Company's
foreign investments. For additional information about the Company's investments
in unconsolidated affiliates, see Note 5. For additional information about the
Company's investments in Brazil and the devaluation of the Brazilian real in
January 1999, see Note 16(a).
(q) Reclassifications and Use of Estimates.
Certain amounts from the previous years have been reclassified to conform
to the 1998 presentation of financial statements. Such reclassifications do not
affect earnings.
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates.
(r) Change in Accounting Principle.
In the fourth quarter of 1998, the Company adopted mark-to-market
accounting for all of the energy price risk management and trading activities of
Reliant Energy Services. Under mark-to-market accounting, the Company records
the fair value of
74
<PAGE> 79
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
energy-related derivative financial instruments, including physical forward
contracts, swaps, options and exchange-traded futures contracts at each balance
sheet date. Such amounts are recorded in the Company's Consolidated Balance
Sheet as price risk management assets, price risk management liabilities,
deferred debits and deferred liabilities. The realized and unrealized gains
(losses) are recorded as a component of operating revenues in the Company's
Consolidated Statements of Income. The Company has applied mark-to-market
accounting retroactively to January 1, 1998. This change was made in order to
adopt a generally accepted accounting methodology that provided consistency
between financial reporting and the methodology used in all reported periods by
the Company in managing its trading activities. There was no material cumulative
effect resulting from the accounting change.
The Company will adopt Emerging Issues Task Force Issue 98-10, "Accounting
for Contracts Involved in Energy Trading and Risk Management Activities" in the
first quarter of 1999 for Reliant Energy Services' trading activities. The
Company does not expect the implementation of EITF Issue 98-10 to be material
to its consolidated financial statements.
(s) New Accounting Pronouncement.
In 2000, the Company expects to adopt Statement of Financial Accounting
Standards No. 133, "Accounting for Derivative Instruments and Hedging
Activities" (SFAS No. 133), which establishes accounting and reporting standards
for derivative instruments, including certain derivative instruments embedded in
other contracts and for hedging activities. The Company is in the process of
determining the effect of adopting SFAS No. 133.
(t) Comprehensive Income.
Accumulated other comprehensive loss at December 31, 1998 included foreign
currency translation adjustments of $34 million and an unrealized loss on
available for sale securities of $16 million, net of tax of $9 million. At
December 31, 1997, accumulated other comprehensive loss included foreign
currency translation adjustments of $.8 million and unrealized loss on available
for sale securities of $6 million, net of tax of $3 million. In 1996,
accumulated other comprehensive loss included foreign currency translation
adjustments of $.4 million.
(u) Other.
For information regarding executive incentive compensation, pensions and
other benefits, see Note 10.
(2) DERIVATIVE FINANCIAL INSTRUMENTS
(a) Price Risk Management and Trading Activities.
The Company, through Reliant Energy Services, offers energy price risk
management services primarily in the natural gas, electric and crude oil and
refined product industries. Reliant Energy Services provides these services by
utilizing, a variety of derivative financial instruments, including fixed and
variable-priced physical forward contracts, fixed-price swap agreements,
variable-price swap agreements, exchange-traded energy futures and option
contracts, and swaps and options traded in the over-the-counter financial
markets (Trading Derivatives). Fixed-price swap agreements require payments to,
or receipts of payments from, counterparties based on the differential between
a fixed and variable price for the commodity. Variable-price swap agreements
require payments to, or receipts of payments from, counterparties based on the
differential between industry pricing publications or exchange quotations.
Prior to 1998, Reliant Energy Services applied hedge accounting to certain
physical commodity activities that qualified for hedge accounting. In 1998,
Reliant Energy Services adopted mark-to-market accounting for all of its price
risk management and trading activities. Accordingly, as of such date such
Trading Derivatives are recorded at fair value with realized and unrealized
gains (losses) recorded as a component of operating revenues in the Company's
Consolidated Statements of Income. The recognized, unrealized balance is
recorded as price risk management assets/liabilities and deferred
debits/credits on the Company's Consolidated Balance Sheets (See Note 1(r)).
75
<PAGE> 80
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The notional quantities, maximum terms and the estimated fair value of
Trading Derivatives at December 31, 1998 are presented below (volumes in
billions of British thermal units equivalent (BBtue) and dollars in millions):
<TABLE>
<CAPTION>
VOLUME-FIXED
VOLUME-FIXED PRICE MAXIMUM
1998 PRICE PAYOR RECEIVER TERM (YEARS)
---- ----------- -------- ------------
<S> <C> <C> <C>
Natural gas.................................................. 937,264 977,293 9
Electricity.................................................. 122,950 124,878 3
Crude oil and products....................................... 205,499 204,223 3
</TABLE>
<TABLE>
<CAPTION>
AVERAGE FAIR
FAIR VALUE VALUE (a)
---------------------- ----------------------
1998 ASSETS LIABILITIES ASSETS LIABILITIES
---- ------ ----------- ------ -----------
<S> <C> <C> <C> <C>
Natural gas.............................................. $ 224 $ 213 $ 124 $ 108
Electricity.............................................. 34 33 186 186
Crude oil and products................................... 29 23 21 17
------ ----------- ------ -----------
$ 287 $ 269 $ 331 $ 311
====== =========== ====== ===========
</TABLE>
The notional quantities, maximum terms and the estimated fair value of
derivative financial instruments at December 31, 1997 are presented below
(volumes in BBtue and dollars in millions):
<TABLE>
<CAPTION>
VOLUME-FIXED
VOLUME-FIXED PRICE MAXIMUM
1997 PRICE PAYOR RECEIVER TERM (YEARS)
---- ----------- -------- ------------
<S> <C> <C> <C>
Natural gas.................................................. 85,701 64,890 4
Electricity.................................................. 40,511 42,976 1
</TABLE>
<TABLE>
<CAPTION>
AVERAGE FAIR
FAIR VALUE VALUE (a)
---------------------- ----------------------
1997 ASSETS LIABILITIES ASSETS LIABILITIES
---- ------ ----------- ------ -----------
<S> <C> <C> <C> <C>
Natural gas.............................................. $ 46 $ 39 $ 56 $ 48
Electricity.............................................. 6 6 3 2
------ ----------- ------ -----------
$ 52 $ 45 $ 59 $ 50
====== =========== ====== ===========
</TABLE>
- ---------
(a) Computed using the ending balance of each month.
In addition to the fixed-price notional volumes above, Reliant Energy
Services also has variable-priced agreements, as discussed above, totaling
1,702,977 and 101,465 BBtue as of December 31, 1998 and 1997, respectively.
Notional amounts reflect the volume of transactions but do not represent the
amounts exchanged by the parties to the financial instruments. Accordingly,
notional amounts do not accurately measure the Company's exposure to market or
credit risks.
All of the fair value shown in the table above at December 31, 1998 and
substantially all of the fair value at December 31, 1997 have been recognized in
income. The fair value as of December 31, 1998 and 1997 was estimated using
quoted prices where available and considering the liquidity of the market for
the Trading Derivatives. The prices are subject to significant changes based on
changing market conditions.
At December 31, 1998, $22 million of the fair value of the assets and $41
million of the fair value of the liabilities are recorded as long-term on
deferred debits and deferred credits, respectively on the Company's Consolidated
Balance Sheets.
The weighted-average term of the trading portfolio, based on volumes, is
less than one year. The maximum and average terms disclosed herein are not
indicative of likely future cash flows, as these positions may be changed by new
transactions in the trading portfolio at any time in response to changing market
conditions, market liquidity and the Company's risk management portfolio needs
and strategies. Terms regarding cash settlements of these contracts vary with
respect to the actual timing of cash receipts and payments.
In addition to the risk associated with price movements, credit risk is
also inherent in the Company and its subsidiaries' risk management activities.
Credit risk relates to the risk of loss resulting from non-performance of
76
<PAGE> 81
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
contractual obligations by a counterparty. The following table shows the
composition of the total price risk management assets of Reliant Energy Services
as of December 31, 1998.
<TABLE>
<CAPTION>
INVESTMENT
GRADE (1) TOTAL
---------------------------------
(Thousands of Dollars)
------------ ------------
<S> <C> <C>
Energy marketers....................................... $ 102,458 $ 123,779
Financial institutions................................. 61,572 61,572
Gas and electric utilities............................. 46,880 48,015
Oil and gas producers.................................. 7,197 8,323
Industrials............................................ 1,807 3,233
Independent power producers............................ 1,452 1,463
Others................................................. 45,421 46,696
------------ ------------
Total............................................. $ 266,787 $ 293,081
============
Credit and other reserves.............................. (6,464)
------------
Energy price risk management assets (2)................ $ 286,617
============
</TABLE>
- ---------
(1) "Investment Grade" is primarily determined using publicly available credit
ratings along with the consideration of credit support (e.g., parent
company guarantees) and collateral, which encompass cash and standby
letters of credit.
(2) The Company has credit risk exposure with respect to two investment grade
customers, each of which represents an amount greater than 5% but less than
10% of Price Risk Management Assets.
(b) Non-Trading Activities.
To reduce the risk from market fluctuations in the price of electric power,
natural gas and related transportation, the Company, Resources and certain of
its subsidiaries enter into futures transactions, swaps and options (Energy
Derivatives) in order to hedge certain natural gas in storage, as well as
certain expected purchases, sales and transportation of natural gas and electric
power (a portion of which are firm commitments at the inception of the hedge).
Energy Derivatives are also utilized to fix the price of compressor fuel or
other future operational gas requirements, although usage to date for this
purpose has not been material. The Company applies hedge accounting with respect
to its derivative financial instruments.
Certain subsidiaries of the Company also utilize interest-rate derivatives
(principally interest-rate swaps) in order to adjust the portion of its overall
borrowings which are subject to interest rate risk and also utilize such
derivatives to effectively fix the interest rate on debt expected to be issued
for refunding purposes.
For transactions involving either Energy Derivatives or interest-rate
derivatives, hedge accounting is applied only if the derivative (i) reduces the
price risk of the underlying hedged item and (ii) is designated as a hedge at
its inception. Additionally, the derivatives must be expected to result in
financial impacts which are inversely correlated to those of the item(s) to be
hedged. This correlation (a measure of hedge effectiveness) is measured both at
the inception of the hedge and on an ongoing basis, with an acceptable level of
correlation of at least 80% for hedge designation. If and when correlation
ceases to exist at an acceptable level, hedge accounting ceases and
mark-to-market accounting is applied.
In the case of interest-rate swaps associated with existing obligations,
cash flows and expenses associated with the interest-rate derivative
transactions are matched with the cash flows and interest expense of the
obligation being hedged, resulting in an adjustment to the effective interest
rate. When interest rate swaps are utilized to effectively fix the interest rate
for an anticipated debt issuance, changes in the market value of the
interest-rate derivatives are deferred and recognized as an adjustment to the
effective interest rate on the newly issued debt.
77
<PAGE> 82
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Unrealized changes in the market value of Energy Derivatives utilized as
hedges are not generally recognized in the Company's Consolidated Statements of
Income until the underlying hedged transaction occurs. Once it becomes probable
that an anticipated transaction will not occur, deferred gains and losses are
recognized. In general, the financial impact of transactions involving these
Energy Derivatives is included in the Company's Statements of Consolidated
Income under the captions (i) fuel expenses, in the case of natural gas
transactions and (ii) purchased power, in the case of electric power
transactions. Cash flows resulting from these transactions in Energy Derivatives
are included in the Company's Statements of Consolidated Cash Flows in the same
category as the item being hedged.
At December 31, 1998, subsidiaries of Resources were fixed-price payors and
fixed-price receivers in Energy Derivatives covering 42,498 billion British
thermal units (Bbtu) and 3,930 BBtu of natural gas, respectively. At December
31, 1997, subsidiaries of Resources were fixed-price payors and fixed-price
receivers in Energy Derivatives covering 38,754 BBtu and 7,647 BBtu of natural
gas, respectively. Also, at December 31, 1998 and 1997, subsidiaries of
Resources were parties to variable-priced Energy Derivatives totaling 21,437
Bbtu and 3,630 BBtu of natural gas, respectively. The weighted average maturity
of these instruments is less than one year.
The notional amount is intended to be indicative of the Company's and its
subsidiaries' 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 Energy
Derivatives 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, as further discussed below. Under such circumstances, gains (losses) are
deferred and recognized as a component of income when the underlying hedged item
is recognized in income.
The average maturity discussed above and the fair value discussed in Note
13 are not necessarily indicative of likely future cash flows as these positions
may be changed by new transactions in the trading portfolio at any time in
response to changing market conditions, market liquidity and the Company's risk
management portfolio needs and strategies. Terms regarding cash settlements of
these contracts vary with respect to the actual timing of cash receipts and
payments.
(c) Trading and Non-trading -- General Policy.
In addition to the risk associated with price movements, credit risk is
also inherent in the Company's and its subsidiaries' risk management activities.
Credit risk relates to the risk of loss resulting from non-performance of
contractual obligations by a counterparty. While as yet the Company and its
subsidiaries have experienced only minor losses due to the credit risk
associated with these arrangements, the Company has off-balance sheet risk to
the extent that the counterparties to these transactions may fail to perform as
required by the terms of each such contract. In order to minimize this risk, the
Company and/or its subsidiaries, as the case may be, enter into such contracts
primarily with those counterparties with a minimum Standard & Poor's or Moody's
rating of BBB- or Baa3, respectively. For long-term arrangements, the Company
and its subsidiaries periodically review the financial condition of such firms
in addition to monitoring the effectiveness of these financial contracts in
achieving the Company's objectives. Should the counterparties to these
arrangements fail to perform, the Company would seek to compel performance at
law or otherwise or obtain compensatory damages in lieu thereof. The Company
might be forced to acquire alternative hedging arrangements or be required to
honor the underlying commitment at then- current market prices. In such event,
the Company might incur additional loss to the extent of amounts, if any,
already paid to the counterparties. In view of its criteria for selecting
counterparties, its process for monitoring the financial strength of these
counterparties and its experience to date in successfully completing these
transactions, the Company believes that the risk of incurring a significant
financial statement loss due to the non-performance of counterparties to these
transactions is minimal.
78
<PAGE> 83
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The Company's policies prohibit the use of leveraged financial instruments.
The Company has established a Corporate Risk Oversight Committee, comprised
of corporate and business segment officers, to oversee all corporate price and
credit risks, including Reliant Energy Services' trading, marketing and risk
management activities. The Corporate Risk Oversight Committee's responsibilities
include reviewing the Company's and its subsidiaries' hedging, trading and price
risk management strategies, activities and limits and monitoring to ensure
compliance with the Company's risk management policies and procedures and
trading limits established by the Company's board of directors.
(3) RATE MATTERS
(a) Electric Proceedings.
The Texas Utility Commission has original (or in some cases appellate)
jurisdiction over Electric Operations' electric rates and services. Texas
Utility Commission orders may be appealed to a District Court in Travis County,
and from that court's decision an appeal may be taken to the Court of Appeals
for the 3rd District at Austin (Austin Court of Appeals). Discretionary review
by the Supreme Court of Texas may be sought from decisions of the Austin Court
of Appeals. In the event that the courts ultimately reverse actions of the Texas
Utility Commission, such matters are remanded to the Texas Utility Commission
for action in light of the courts' orders.
(b) Transition Plan.
In June 1998, the Texas Utility Commission issued an order in Docket No.
18465 approving the Company's Transition Plan filed by Electric Operations in
December 1997. The Transition Plan included base rate credits to residential
customers of 4% in 1998 and an additional 2% in 1999. Commercial customers whose
monthly billing is 1,000 kva or less are entitled to receive base rate credits
of 2% in each of 1998 and 1999. The Company implemented the Transition Plan
effective January 1, 1998.
For information about additional depreciation of generation assets and
redirecting depreciation pursuant to the Transition Plan, see Note 1(f).
Review of the Texas Utility Commission's order in Docket No. 18465 is
currently pending before the Travis County District Court. In August 1998, the
Office of the Attorney General for the State of Texas and a Texas municipality
filed an appeal seeking, among other things, to reverse the portion of the Texas
Utility Commission's order relating to the redirection of depreciation expenses
under the Transition Plan. Because of the number of variables that can affect
the ultimate resolution of an appeal of Commission orders, the Company is not in
a position at this time to predict the outcome of this matter or the ultimate
effect that adverse action by the courts could have on the Company.
(4) JOINTLY OWNED ELECTRIC UTILITY PLANT
(a) Investment in South Texas Project.
The Company has a 30.8% interest in the South Texas Project, which consists
of two 1,250 megawatt (MW) nuclear generating units and bears a corresponding
30.8% share of capital and operating costs associated with the project. As of
December 31, 1998, the Company's investment in the South Texas Project
(including AFUDC) was $1.4 billion (net of $1.1 billion accumulated
depreciation). The Company's investment in nuclear fuel (including AFUDC) was
$41 million (net of $230 million amortization) as of such date.
79
<PAGE> 84
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The South Texas Project is owned as a tenancy in common among its four
co-owners, with each owner retaining its undivided ownership interest in the two
nuclear-fueled generating units and the electrical output from those units. The
four co-owners have delegated management and operation responsibility for the
South Texas Project to the South Texas Nuclear Operating Company (STPNOC).
STPNOC is managed by a board of directors comprised of one director from each of
the four owners, along with the chief executive officer of STPNOC. The four
owners provide oversight through an owners' committee comprised of
representatives of each of the owners and through the board of directors of
STPNOC. Prior to November 1997, the Company was the operator of the South Texas
Project.
(b) Nuclear Insurance.
The Company and the other owners of the South Texas Project maintain
nuclear property and nuclear liability insurance coverage as required by law and
periodically review available limits and coverage for additional protection. The
owners of the South Texas Project currently maintain $2.75 billion in property
damage insurance coverage, which is above the legally required minimum, but is
less than the total amount of insurance currently available for such losses.
This coverage consists of $500 million in primary property damage insurance and
excess property insurance in the amount of $2.25 billion. With respect to excess
property insurance, the Company and the other owners of the South Texas Project
are subject to assessments, the maximum aggregate assessment under current
policies being $16.5 million during any one policy year. The application of the
proceeds of such property insurance is subject to the priorities established by
the Nuclear Regulatory Commission (NRC) regulations relating to the safety of
licensed reactors and decontamination operations.
Pursuant to the Price Anderson Act, the maximum liability to the public of
owners of nuclear power plants, such as the South Texas Project, was $9.145
billion as of December 31, 1998. Owners are required under the Price Anderson
Act to insure their liability for nuclear incidents and protective evacuations
by maintaining the maximum amount of financial protection available from private
sources and by maintaining secondary financial protection through an industry
retrospective rating plan. The assessment of deferred premiums provided by the
plan for each nuclear incident is up to $83.9 million per reactor, subject to
indexing for inflation, a possible 5% surcharge (but no more than $10 million
per reactor per incident in any one year) and a 3% state premium tax. The
Company and the other owners of the South Texas Project currently maintain the
required nuclear liability insurance and participate in the industry
retrospective rating plan.
There can be no assurance that all potential losses or liabilities will be
insurable, or that the amount of insurance will be sufficient to cover them. Any
substantial losses not covered by insurance would have a material effect on the
Company's financial condition, results of operations and cash flows.
(c) Nuclear Decommissioning.
The Company contributes $14.8 million per year to a trust established to
fund its share of the decommissioning costs for the South Texas Project. For a
discussion of the accounting treatment for the securities held in the Company's
nuclear decommissioning trust, see Note 1(o). In May 1994, an outside consultant
estimated the Company's portion of decommissioning costs to be approximately
$318 million (1994 dollars). The consultant's calculation of decommissioning
costs for financial planning purposes used the DECON methodology (prompt
removal/dismantling), one of the three alternatives acceptable to the NRC and
assumed deactivation of Units Nos. 1 and 2 upon the expiration of their 40-year
operating licenses. While the current and projected funding levels currently
exceed minimum NRC requirements, no assurance can be given that the amounts held
in trust will be adequate to cover the actual decommissioning costs of the South
Texas Project. Such costs may vary because of changes in the assumed date of
decommissioning, changes in regulatory and accounting requirements, changes in
technology and changes in costs of labor, materials and equipment. An update of
the 1994 study is in the process of being completed.
80
<PAGE> 85
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(d) Assessment Fees for Spent Fuel Disposal and Enrichment and Decommissioning.
By contract, the United States Department of Energy (DOE) has committed
itself ultimately to take possession of all spent fuel generated by the South
Texas Project. The DOE contract currently requires payment of a spent fuel
disposal fee on nuclear plant-generated electricity of one mill (one-tenth of a
cent) per net KWH sold. This fee is subject to adjustment to ensure full cost
recovery by the DOE. The Energy Policy Act also includes a provision that
assesses a fee upon domestic utilities that purchased nuclear fuel enrichment
services from the DOE before October 24, 1992. The South Texas Project's
assessment is approximately $2 million per year (subject to escalation for
inflation). The Company has a remaining estimated liability of $5 million for
such assessments.
(e) 1996 Settlement of South Texas Project Litigation.
In 1996, the Company recorded an aggregate $95 million ($62 million net of
tax) charge in connection with various settlements of lawsuits filed by
co-owners of the South Texas Project. For information about the execution of an
operations agreement with the City of San Antonio in connection with one of
these settlements, see Note 12(c).
(5) EQUITY INVESTMENTS AND ADVANCES TO UNCONSOLIDATED SUBSIDIARIES
The Company accounts for affiliate investments of its subsidiaries under
the equity method of accounting where (i) the subsidiary's ownership interest in
the affiliate ranges from 20% to 50%, (ii) the ownership interest is less than
20% but the subsidiary exercises significant influence over operating and
financial policies of such affiliate or (iii) the subsidiary's ownership
interest in the affiliate exceeds 50% but the subsidiary does not exercise
control over the affiliate.
The Company's and its subsidiaries' equity investments and advances in
unconsolidated subsidiaries at December 31, 1998 and 1997 were $1 billion and
$704 million, respectively. The Company's and its subsidiaries' equity income
from these investments, included in International revenues and other net income,
was $71 million, $49 million and $17 million in 1998, 1997 and 1996,
respectively. Dividends received from the investments amounted to $44 million
and $46 million in 1998 and 1997, respectively. No dividends were received from
these investments in 1996.
(a) International.
In April 1998, Light ServiHos de Eletricidade S.A. (Light), a
Brazilian corporation in which Reliant Energy International, Inc. (Reliant
Energy International) indirectly owns an 11.69% common stock interest, purchased
74.88% of the common stock of Metropolitana Eletricidade de Sao Paulo S.A.
(Metropolitana), an electric distribution company that serves the metropolitan
area of Sao Paulo, Brazil. The purchase price for the shares was approximately
$1.8 billion and was financed with proceeds from bank borrowings. As of December
31, 1998, Light and Metropolitana had approximately $3.2 billion in non-local
currency denominated borrowings. For information regarding foreign currency
adjustments, see Note 1(p). For information about the devaluation of the
Brazilian real in January 1999, see Note 16(a).
In May 1997, Reliant Energy International increased its indirect ownership
interest in an Argentine electric utility from 48% to 63%. The purchase price
of the additional interest was $28 million.
On June 30, 1998, Reliant Energy International sold its 63% ownership
interest in an Argentine affiliate and certain related assets for approximately
$243 million. Reliant Energy International acquired its initial ownership
interests in the electric utility in 1992. The Company recorded an $80 million
after-tax gain from this sale in the second quarter of 1998.
In 1998, a subsidiary of Reliant Energy International acquired for
approximately $150 million, equity interests (currently ranging from
approximately 36% to 45%) in three electric distribution systems located in El
Salvador. Corporacion EDC S.A.C.A. (CEDC), Reliant Energy International's
partner in this venture, acquired majority interests in the systems when they
were privatized in early 1998. On June 30, 1998, CEDC closed on the sale of
approximately half of its interests in the systems to a subsidiary of Reliant
Energy International.
81
<PAGE> 86
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In August 1998, Reliant Energy International and CEDC jointly acquired,
through subsidiaries, 65% of the stock of two Colombian electric distribution
companies, Electricaribe and Electrocosta. The shares of these companies are
indirectly held by an offshore holding company jointly owned by special purpose
subsidiaries of CEDC and Reliant Energy International.
The purchase price for the joint investment in Electricaribe and
Electrocosta was approximately $522 million, excluding transaction costs. The
purchase price was funded with capital contributions from Reliant Energy
International and CEDC and a U.S. $200 million loan obtained by the holding
company from a United States bank. A $100 million advance on the loan was
obtained in October 1998 with subsequent advances of $25 million and $75 million
obtained in December 1998 and January 1999, respectively. The loan will mature
on October 31, 2003. Reliant Energy International funded its capital
contributions with a portion of the proceeds from the sale of the Argentine
affiliate discussed above and capital contributions from the Company. Under the
terms of a support agreement, Reliant Energy International and CEDC have agreed,
among other things, to repurchase up to U.S. $50 million of the loan from the
bank to the extent that the bank is unable to syndicate that portion of the loan
to other banks on or prior to June 15, 1999.
In June 1997, a consortium of investors which included a subsidiary of
Reliant Energy International, acquired for $496 million a 56.7% controlling
ownership interest in Empresa de Energia del Pacifico S.A.E.S.P. (EPSA), an
electric utility system serving the Valle de Cauca province of Colombia,
including the area surrounding the city of Cali. Reliant Energy International
contributed $152 million of the purchase price for a 28.35% ownership interest
in EPSA. In addition to its distribution facilities, EPSA owns 850 MW of
electric generation capacity.
Reliant Energy International has accounted for these transactions under
purchase accounting and has recorded its investments and its interest in the
affiliates' earnings after the acquisition dates using the equity method. The
purchase prices were allocated, on a preliminary basis, using the estimated fair
market values of the assets acquired and the liabilities assumed as of the dates
of acquisition. The differences between the amounts paid and the underlying fair
values of the net assets acquired are being amortized as a component of earnings
attributable to unconsolidated affiliates over the estimated lives of the
projects ranging from 30 to 40 years. Purchase price adjustments to fixed assets
are being amortized over the underlying assets' estimated useful lives.
(b) Combined Financial Statement Data of Equity Investments and Advances to
Unconsolidated Subsidiaries.
The following table sets forth certain summarized financial information of
the Company's unconsolidated affiliates as of December 31, 1998 and 1997 and for
the years then ended or periods from the respective affiliates' acquisition date
through December 31, 1998, 1997 and 1996, if shorter:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
----------------------------------------------------------
1998 1997 1996
---------------- ---------------- ----------------
($ IN THOUSANDS)
<S> <C> <C> <C>
Income Statement:
Revenues....................... $ 2,449,335 $ 2,011,927 $ 994,743
Operating Expenses............. 1,762,166 1,460,248 768,993
Net Income..................... 514,005 403,323 149,038
</TABLE>
82
<PAGE> 87
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-------------------------------------
1998 1997
---------------- ----------------
($ IN THOUSANDS)
<S> <C> <C>
Balance Sheet:
Current Assets................... $ 1,841,857 $ 726,997
Noncurrent Assets................ 13,643,747 5,791,858
Current Liabilities.............. 4,074,603 566,596
Noncurrent Liabilities........... 6,284,821 1,398,385
Owner's Equity................... 5,126,180 4,553,874
</TABLE>
(6) COMMON STOCK
At December 31, 1998 and 1997 the Company had 296,271,063 and 295,357,276
shares of common stock issued, respectively (out of a total of 700,000,000
authorized shares).
At December 31, 1998 and 1997, the Company had 284,494,195 and 282,875,266
common shares outstanding, respectively. Outstanding common shares exclude (i)
shares pledged to secure a loan to the Company's Employee Stock Ownership Plan
(11,674,063 and 12,388,551 at December 31, 1998 and 1997, respectively) and (ii)
treasury shares (102,805 and 93,459 at December 31, 1998 and 1997,
respectively). At December 31, 1998 and 1997, the treasury shares of common
stock held by the Company represent shares which were received from holders of
Company stock options who surrendered shares of Company common stock as partial
payment for the exercise price of their stock options.
In 1998, the Company paid four regular quarterly dividends aggregating
$1.50 per share on its common stock pursuant to dividend declarations made in
December 1997, March 1998, June 1998 and September 1998. In December 1998, the
Company declared its regular quarterly dividend of $0.375 per share to be paid
in March 1999. For information regarding certain restrictions on payments of
dividends, see Note 8(c).
(7) PREFERRED AND PREFERENCE STOCK
(a) Preferred Stock.
At December 31, 1998 and 1997, the Company had 10,000,000 authorized shares
of preferred stock, of which 97,397 shares were outstanding. As of such date,
the Company's only outstanding series of preferred stock was its $4.00 Preferred
Stock. The $4.00 Preferred Stock pays an annual dividend of $4.00 per share, is
redeemable at $105 per share and has a liquidation price of $100 per share.
(b) Preference Stock.
At December 31, 1998 and 1997, the Company had 10,000,000 authorized shares
of preference stock, of which 700,000 shares are classified as Series A
Preference Stock and 27,000 shares are classified as Series B Preference Stock.
As of December 31, 1998 and 1997, there were no shares of Series A Preference
Stock issued and outstanding (such shares being issuable in accordance with the
Company's Shareholder Rights Agreement upon the occurrence of certain events).
The number of shares of Series B Preference Stock issued and outstanding as of
December 31, 1998 and 1997 was 17,000. On March 27, 1998, the Company designated
1,575 shares of its preference stock as Series C Preference Stock. As of
December 31, 1998, the number of shares of Series C Preference Stock issued and
outstanding was 1,575. The shares of Series B and Series C Preference Stock are
not deemed outstanding for financial reporting purposes because they are held by
wholly owned financing subsidiaries of the Company. See Note 8(c).
83
<PAGE> 88
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Each share of common stock of the Company includes one associated
preference stock purchase right (Company Right). Under certain circumstances,
each Company Right entitles the registered holder to purchase from the Company a
unit consisting of one-thousandth of a share (Fractional Share) of Series A
Preference Stock, without par value (Series A Preference Stock), at a purchase
price of $42.50 per Fractional Share, subject to adjustments. The shareholder
rights plan was adopted by the shareholders of Former Parent in August 1990 and
was assumed by the Company, with certain amendments, effective upon the Merger.
(8) LONG-TERM DEBT AND SHORT-TERM BORROWINGS
(a) Consolidated Debt.
The Company's consolidated long-term and short-term debt outstanding is
summarized in the following table. Of the amount of long-term and short-term
debt outstanding as of December 31, 1998, $2 billion represents debt of
Resources which was adjusted to fair market value as of the Acquisition Date.
CONSOLIDATED LONG-TERM DEBT AND SHORT-TERM BORROWINGS
(IN MILLIONS)
<TABLE>
<CAPTION>
DECEMBER 31, 1998 DECEMBER 31, 1997
--------------------------- ---------------------------
LONG-TERM CURRENT(1) LONG-TERM CURRENT(1)
----------- ----------- ----------- -----------
<S> <C> <C> <C> <C>
Short-term Borrowings:
Commercial Paper................... $ 1,360 $ 1,435
Lines of Credit.................... 150 390
Resources Receivables Facility..... 300 300
Notes Payables..................... 3
----------- ----------- ----------- -----------
Total Short-term Borrowings........... 1,813 2,125
----------- ----------- ----------- -----------
Long-term Debt-net:
ACES............................... $ 2,350 $ 1,174
Debentures(2)(3)................... 1,482 669
First Mortgage Bonds(2)............ 1,866 170 2,495
Pollution Control Bonds............ 581 118 5
Resources Medium-term Notes(3)..... 178 182 79
Notes Payable(3)................... 330 226 565 166
Capital Leases..................... 14 1 15 1
----------- ----------- ----------- -----------
Total Long-term Debt.................. 6,801 397 5,218 251
----------- ----------- ----------- -----------
Total Borrowings................... $ 6,801 $ 2,210 $ 5,218 $ 2,376
=========== =========== =========== ===========
</TABLE>
- ----------
(1) Includes amounts due within one year of the date noted.
(2) Includes unamortized discount related to debentures of approximately $1
million at December 31, 1998 and 1997 and unamortized premium related to
debentures of approximately $17 million at December 31, 1998. The
unamortized discount related to first mortgage bonds was approximately $10
million and $14 million at December 31, 1998 and 1997, respectively.
(3) Includes unamortized premium related to fair value adjustments of
approximately $18.1 million and $15.8 million for Debentures at December
31, 1998 and 1997, respectively. The unamortized premium for Resources
long-term and medium-term notes at December 31, 1998 was approximately $12
million and $0, respectively, and $0 and $3 million at December 31 1997,
respectively. The unamortized premium for long-term and current notes
payable was approximately $3 million each at December 31, 1998 and $14
million and $3 million, respectively at December 31, 1997. See Note 1(b).
84
<PAGE> 89
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Consolidated maturities of long-term debt and sinking fund requirements for
the Company (including Resources) are approximately $402 million in 1999, $2.8
billion in 2000, $438 million in 2001, $1.9 billion in 2002 and $199 million in
2003.
(b) First Mortgage Bonds.
As of December 31, 1998, the Company had an aggregate of $2.0 billion
principal amount of its first mortgage bonds issued and outstanding.
Sinking or improvement fund requirements of the Company's first mortgage
bonds outstanding will be approximately $24 million in 1999, $17 million in
2000, $16 million in 2001 and 2002 and $13 million in 2003. Such requirements
may be satisfied by certification of property additions at 100% of the
requirements. Sinking or improvement fund requirements for 1998 and prior years
have been satisfied by certification of property additions.
The Company has agreed to expend an amount each year for replacements and
improvements in respect of its depreciable mortgaged utility property equal to
$1,450,000 plus 2% of net additions to such mortgaged property made after March
31, 1948 and before July 1 of the preceding year. Such requirement may be met
with cash, first mortgage bonds, gross property additions or expenditures for
repairs or replacements, or by taking credit for property additions at 100% of
the requirements. The replacement fund requirement to be satisfied in 1999 is
approximately $316.6 million.
The amount of the first mortgage bonds that may be issued by the Company is
unlimited as to issuance, but limited by property, earnings and other provisions
of the Mortgage and Deed of Trust dated as of November 1, 1944, between the
Company and South Texas Commercial National Bank of Houston (Chase Bank of
Texas, National Association, as Successor Trustee) and the supplemental
indentures thereto. Substantially all physical assets used in the conduct of the
business and operations of Electric Operations are subject to liens securing the
long-term debt under the mortgage.
(c) FinanceCo and FinanceCo II Credit Facilities.
In August 1997, a limited partnership special purpose subsidiary of the
Company (FinanceCo) established a five-year, $1.644 billion revolving credit
facility (FinanceCo Facility). The FinanceCo Facility supported $1.360 billion
in commercial paper borrowings by FinanceCo at December 31, 1998 recorded as
notes payable on the Company's Consolidated Balance Sheet. The weighted average
interest rate of these borrowings was 5.88% at December 31, 1998, and 6.15%
at December 31, 1997.
Borrowings under the FinanceCo Facility bear interest at a rate based upon
the London interbank offered rate (LIBOR) plus a margin, a base rate or at a
rate determined through a bidding process. The FinanceCo Facility may be used
(i) to support the issuance of commercial paper or other short-term indebtedness
of FinanceCo, (ii) subject to certain limitations, to finance purchases of
Company common stock and (iii) subject to certain limitations, to provide funds
for general purposes of FinanceCo, including the making of intercompany loans
to, or securing letters of credit for the benefit of, FinanceCo's affiliates.
The FinanceCo Facility requires the Company to maintain a ratio of
consolidated indebtedness for borrowed money to consolidated capitalization (as
defined) that does not exceed 0.65:1.00. The FinanceCo Facility also contains
restrictions applicable to the Company and certain of its subsidiaries with
respect to, among other things, (i) liens, (ii) consolidations, mergers and
dispositions of assets, (iii) dividends and purchases of common stock, (iv)
certain types of investments and (v) certain changes in its business. The
FinanceCo Facility contains customary covenants and default provisions
applicable to FinanceCo and its subsidiaries, including limitations on, among
other things, additional indebtedness (other than certain permitted
indebtedness), liens and certain investments or loans.
85
<PAGE> 90
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Subject to certain conditions and limitations, the Company is required to
make cash payments from time to time to FinanceCo from excess cash flow (as
defined in the FinanceCo Facility) to the extent necessary to enable FinanceCo
to meet its financial obligations. At December 31, 1998, commercial paper
supported by the FinanceCo Facility was secured by pledges of (i) all of the
limited and general partner interests of FinanceCo, (ii) the Series B Preference
Stock and (iii) certain intercompany notes held by FinanceCo. The obligations
under the FinanceCo Facility are not secured by the utility assets of the
Company or Resources or by the Company's investment in Time Warner securities.
In March 1998, a limited partnership special purpose subsidiary of the
Company (FinanceCo II) executed a $150 million credit agreement (FinanceCo II
Facility) which terminated March 2, 1999. Proceeds from $150 million of
borrowings under the FinanceCo II Facility were used to fund a portion of the
April 1998 purchase by Reliant Energy Power Generation, Inc. (Power Generation)
of four electric generation plants. Borrowings under the FinanceCo II Facility
bore interest at LIBOR-based and negotiated rates. At December 31, 1998,
FinanceCo II had $150 million of borrowings under this facility at an interest
rate of 5.75%. In March 1999, the $150 million of borrowings under the FinanceCo
II facility were paid at maturity with borrowings under the FinanceCo facility.
(d) Company Credit Facility.
The Company meets its short-term financing needs primarily through sales of
commercial paper supported by a $200 million revolving credit facility.
Borrowings under the facility are unsecured and a facility fee is paid. At
December 31, 1998, there was no outstanding commercial paper and there were no
outstanding borrowings under the bank facility.
(e) ACES.
For information regarding the Company's ACES, including certain accounting
losses that may result upon increases in the price of Time Warner common stock,
see Note 1(n).
(f) Pollution Control Revenue Bonds.
In January 1998, the Matagorda County Navigation District Number One (MCND)
issued on behalf of the Company $104.7 million aggregate principal amount of
pollution control revenue refunding bonds ($29.7 million at 5.25% and $75
million at 5.15%). The MCND bonds will mature in 2029. Proceeds from the
issuance were used in February 1998 to redeem all outstanding 7 7/8% MCND Series
1989A pollution control revenue bonds ($29.7 million) and 7.70% MCND Series
1989B pollution control revenue bonds ($75 million) at a redemption price of
102% of the aggregate principal amount of each series.
In February 1998, the Brazos River Authority (BRA) issued on behalf of the
Company $290 million aggregate principal amount of pollution control revenue
refunding bonds. The BRA bonds will mature in May 2019 ($200 million at 5 1/8%)
and November 2020 ($90 million at 5 1/8%). Proceeds from the issuance were used
in May 1998 to redeem all outstanding 8.25% BRA Series 1988A pollution control
revenue bonds ($100 million), 8.25% BRA Series 1988B pollution control revenue
bonds ($90 million) and 8.10% BRA Series 1988C pollution control revenue bonds
($100 million) at a redemption price of 102% of the aggregate principal amount
of each series.
In June 1998, the Company repaid at maturity $5 million of its
floating-rate pollution control revenue bonds issued on its behalf.
In September 1998, pollution control revenue refunding bonds aggregating
$68.7 million were issued on behalf of the Company by the BRA. The bonds bear an
interest rate of 4.9% and mature in October 2015. Proceeds from the issuance
were used in October 1998 to redeem $68.7 million principal amount of the 7 3/4%
BRA Series 1988D pollution control bonds at a redemption price of 102% of the
aggregate principal amount.
86
<PAGE> 91
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In November 1998, the Company changed the interest rate determination
method for (i) the MCND Series 1997 pollution control revenue refunding bonds
due November 2028 ($68 million aggregate principal amount outstanding) and (ii)
the BRA Series 1997 pollution control revenue refunding bonds due November 2018
($50 million aggregate principal amount outstanding). The method by which
interest on the bonds is determined changed from a floating rate mode to a
long-term fixed rate mode. The interest rate for the MCND Series 1997 bonds will
be 5 1/8% until maturity of the bonds, and the interest rate for the BRA Series
1997 bonds will be 5.05% until maturity of the bonds. The MCND and BRA Series
1997 bonds, which were issued in January 1997, were mandatorily tendered in
November 1998 in connection with the change in the interest rate determination
method. The purchase price of the tendered bonds (100% of their principal amount
plus accrued interest) was funded with the proceeds from a remarketing of the
fixed-rate bonds.
(g) Resources Credit Facilities.
In 1998, Resources met its short-term financing needs primarily through a
bank facility, bank lines of credit, a receivables facility and the issuance of
commercial paper. In March 1998, Resources replaced its $400 million revolving
credit facility with a five-year $350 million revolving credit facility
(Resources Credit Facility). Borrowings under the Resources Credit Facility are
unsecured and bear interest at a rate based upon either LIBOR plus a margin, a
base rate or a rate determined through a bidding process. The Resources Credit
Facility is used to support Resources' issuance of up to $350 million of
commercial paper. There were no commercial paper borrowings and no loans
outstanding under the Resources Credit Facility at December 31, 1998. Borrowings
under Resources' prior credit facility at December 31, 1997 were $340 million.
In addition, Resources had $50 million of outstanding loans under uncommitted
lines of credit at December 31, 1997 having a weighted average interest rate of
6.829%.
A $65 million committed bank facility under which Resources obtained
letters of credit and all of Resources' uncommitted lines of credit were
terminated in 1998. Subsequent to the December 1998 termination, Resources
obtained letters of credit under an uncommitted line. Resources expects to amend
the Resources Credit Facility in March 1999 to add a $65 million letter of
credit subfacility.
Under a trade receivables facility (Receivables Facility) which expires in
August 1999, Resources sells, with limited recourse, an undivided interest
(limited to a maximum of $300 million) in a designated pool of its and certain
of its subsidiaries' accounts receivable. The amount of receivables sold and
uncollected was $300 million at December 31, 1998 and 1997, respectively. The
weighted average interest rate was approximately 5.54% and 5.65% at December 31,
1998 and 1997, respectively. Certain of the remaining receivables serve as
collateral for receivables sold and represent the maximum exposure to Resources
should all receivables sold prove ultimately uncollectible. Resources has
retained servicing responsibility under the Receivables Facility for which it is
paid a servicing fee. Pursuant to SFAS No. 125, "Accounting for Transfers and
Servicing of Financial Assets and Extinguishments Liabilities" (SFAS No. 125),
the receivables are recorded as assets and amounts received by Resources under
the Receivables Facility are recorded as notes payable.
87
<PAGE> 92
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(h) Resources Long-term Debt.
At December 31, 1998, Resources had issued and outstanding $109.6 million
aggregate principal amount of its 6% Convertible Subordinated Debentures due
2012 (Subordinated Debentures). The holders of the Subordinated Debentures
receive interest quarterly and have the right at any time on or before the
maturity date thereof to convert each Subordinated Debenture into 0.65 shares of
Company common stock and $14.24 in cash. Resources is required to make annual
sinking fund payments of $6.5 million on the Subordinated Debentures, which
began on March 15, 1997 and on each succeeding March 15 up to and including
March 15, 2011. Resources (i) may credit against the sinking fund requirements
any Subordinated Debentures redeemed by Resources and Subordinated Debentures
which have been converted at the option of the holder and (ii) may deliver
purchased Subordinated Debentures in satisfaction of the sinking fund
requirements. During 1998, Resources purchased $6.7 million aggregate principal
amount of its Subordinated Debentures at an average purchase price of 97.3% of
the aggregate principal amount plus accrued interest.
In February 1998, Resources issued $300 million principal amount of 6.5%
debentures due February 1, 2008. The proceeds from the sale of the debentures
were used to repay short-term indebtedness of Resources, including the
indebtedness incurred in connection with the 1997 purchase of $101 million
aggregate principal amount of its 10% debentures and the repayment of $53
million aggregate principal amount of Resources debt that matured in December
1997 and January 1998. In connection with the issuance of the 6.5% debentures,
Resources received approximately $1 million upon unwinding a $300 million
treasury rate lock agreement, which was tied to the interest rate on 10-year
treasury bonds. The rate lock agreement was executed in January 1998, and
proceeds from the unwind will be amortized over the 10 year life of Resources'
6.5% debentures.
During 1998, Resources repaid the following medium-term notes at maturity:
<TABLE>
<CAPTION>
Series Principal Amount
-------------------------------------- ----------------
($ in millions)
<S> <C>
9.30% due January 15, 1998 $ 1.0
8.74% due May 14, 1998 20.0
8.76% due May 14, 1998 5.0
8.73% due May 15, 1998 3.0
9.07% due July 20, 1998 15.0
8.60% due September 1, 1998 3.0
8.58% due September 1, 1998 5.0
8.64% due September 4, 1998 12.5
8.50% due September 14, 1998 0.5
8.60% due September 15, 1998 6.0
8.43% due September 17, 1998 5.0
-----------
Total $ 76.0
===========
</TABLE>
In November 1998, Resources sold $500 million aggregate principal amount of
its 6 3/8% Term Enhanced ReMarketable Securities (TERM Notes). Included within
the TERM Notes is an embedded option sold to an investment bank which gives the
investment bank the right to remarket the TERM Notes in 2003 if it chooses to
exercise the option. The net proceeds of $514 million from the offering of the
TERM Notes were used for general corporate purposes, including the repayment of
(i) $178.5 million of Resources' outstanding commercial paper and (ii) a $150
million term loan of Resources that matured on November 13, 1998. The TERM Notes
are unsecured obligations of Resources which bear interest at an annual rate of
6 3/8% through November 1, 2003. On November 1, 2003, the holders of the TERM
Notes are required to tender their notes at 100% of their principal amount. The
portion of the proceeds attributable to the option premium will be amortized
over the stated term of the securities. If the option is not exercised,
Resources will repurchase the TERM Notes at 100% of their principal amount on
November 1, 2003. If the option is exercised, the TERM Notes will be remarketed
on a date, selected by Resources,
88
<PAGE> 93
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
within the 52-week period beginning November 1, 2003. During such period and
prior to remarketing, the TERM Notes will bear interest at rates, adjusted
weekly, based on an index selected by Resources. If the TERM Notes are
remarketed, the final maturity date of the TERM Notes will be November 1, 2013,
subject to adjustment, and the effective interest rate on the remarketed TERM
Notes will be 5.66% plus Resources' applicable credit spread at the time of such
remarketing.
(i) Restrictions on Resources' Debt.
Under the provisions of Resources Credit Facility, Resources' total debt is
limited to 55% of its total capitalization. At December 31, 1998, this provision
did not significantly restrict Resources' ability to issue debt or to pay
dividends. At December 31, 1998, Resources ratio of total debt to total
capitalization was 40.13%.
(j) Reliant Energy International Debt.
In 1996, a subsidiary of Reliant Energy International entered into a $167.5
million loan agreement in order to refinance a portion of the acquisition costs
of Light. The full proceeds of the loan, net of a $17.5 million debt reserve
account established for the benefit of the lenders, were funded in April 1997.
The loan (included in Long-term debt) is secured by, among other things, a
pledge of the shares of Light and of a subsidiary of Reliant Energy
International that is the indirect holder of the shares of Light.
(9) TRUST SECURITIES
(a) Company.
In February 1997, two Delaware statutory business trusts (Reliant Trusts)
established by the Company issued (i) $250 million of preferred securities and
(ii) $100 million of capital securities, respectively. The preferred securities
have a distribution rate of 8.125% payable quarterly in arrears, a stated
liquidation amount of $25 per preferred security and must be redeemed by March
2046. The capital securities have a distribution rate of 8.257% payable
quarterly in arrears, a stated liquidation amount of $1,000 per capital security
and must be redeemed by February 2037.
The Reliant Trusts sold the preferred and capital securities to the public
and used the proceeds to purchase $350 million aggregate principal amount of
subordinated debentures (Debentures) from the Company having interest rates
corresponding to the distribution rates of the securities and maturity dates
corresponding to the mandatory redemption dates of the securities. The Reliant
Trusts are accounted for as wholly owned consolidated subsidiaries of the
Company. The Debentures represent the Reliant Trusts' sole assets and its entire
operations. The Company has fully and unconditionally guaranteed, on a
subordinated basis, each Trust's obligations, including the payment of
distributions and all other payments due with respect to the respective
preferred and capital securities. The preferred and capital securities are
mandatorily redeemable upon the repayment of the related Debentures at their
stated maturity or earlier redemption.
Subject to certain limitations, the Company has the option of deferring
payments of interest on the Debentures held by the Reliant Trusts. If and for as
long as interest payments on the Debentures have been deferred, or an event of
default under the indenture relating thereto has occurred and is continuing, the
Company may not pay dividends on its capital stock. As of December 31, 1998, no
interest payments on the Debentures had been deferred.
(b) Resources.
In June 1996, a Delaware statutory business trust (Resources Trust)
established by Resources issued in a public offering $172.5 million of
convertible preferred securities and sold approximately $5.3 million of
Resources Trust common securities (106,720 securities, representing 100% of the
Resources Trust's common equity) to Resources. The
89
<PAGE> 94
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
convertible preferred securities have a distribution rate of 6.25% payable
quarterly in arrears, a stated liquidation amount of $50 per convertible
preferred security and must be redeemed by 2026. The Resources Trust sold the
convertible preferred securities to the public and used the proceeds, in
addition to the common securities proceeds, to purchase $177.8 million of 6.25%
Convertible Junior Subordinated Debentures from Resources, which Debentures have
an interest rate corresponding to the distribution rate of the convertible
preferred securities and a maturity date corresponding to the mandatory
redemption date of the convertible preferred securities. The Resources Trust is
accounted for as a wholly owned consolidated subsidiary of Resources. The junior
subordinated debentures represent the sole assets of the Resources Trust and its
entire operations. Resources has fully and unconditionally guaranteed, on a
subordinated basis, the Resources Trust's obligations, including the payment of
distributions and all other payments, with respect to the convertible preferred
securities. The convertible preferred securities are mandatorily redeemable upon
the repayment of the related junior subordinated debentures at their stated
maturity or earlier redemption. Each convertible preferred security is
convertible at the option of the holder into $33.62 of cash and 1.55 shares of
Company common stock. During 1998, convertible preferred securities aggregating
$15.5 million were converted, leaving $0.9 million liquidation amount of
convertible preferred securities outstanding at December 31, 1998.
Subject to certain limitations, Resources has the option of deferring
payments of interest on the Debentures held by the Resources Trust. If and for
as long as interest payments on the Debentures have been deferred, or on event
of default under the indenture relating thereto has occurred and is continuing,
Resources may not pay dividends on its capital stock. As of December 31, 1998,
no interest payments on the Debentures had been deferred.
(10) STOCK-BASED INCENTIVE COMPENSATION PLANS AND RETIREMENT PLANS
(a) Incentive Compensation Plans.
The Company has Long-Term Incentive Compensation Plans (LICP) and other
incentive compensation plans that provide for the issuance of stock-based
incentives (including performance-based stock compensation and restricted
shares, stock options and stock appreciation rights) to key employees of the
Company, including officers. As of December 31, 1998, 273 current and former
employees participated in the plans. A maximum of approximately 9 million shares
of common stock may be issued under these plans. Under the LICP, beginning one
year after the grant date, the options become exercisable in one-third
increments each year. Performance-based stock compensation issued and restricted
shares granted were 98,413 in 1998, 704,865 in 1997 and 69,905 in 1996.
90
<PAGE> 95
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Stock option activity for the years 1996 through 1998 is summarized below:
<TABLE>
<CAPTION>
WEIGHTED AVERAGE
NUMBER PRICE AT DATE OF
OF SHARES GRANT OR EXERCISE
--------- -----------------
<S> <C> <C>
Outstanding at December 31, 1995......................................... 411,342 $ 21.1414
Options Granted........................................................ 101,798 $ 24.375
Options Exercised...................................................... (574) $ 17.75
Options Withheld for Taxes............................................. (90)
Options Canceled....................................................... (13,824)
Outstanding at December 31, 1996......................................... 498,652 $ 21.7796
Options Granted........................................................ 382,954 $ 21.0673
Options Converted at Acquisition(1).................................... 622,504 $ 12.9002
Options Exercised(1)................................................... (281,053) $ 9.2063
Options Withheld for Taxes............................................. (72)
Options Canceled....................................................... (148,418)
Outstanding at December 31, 1997......................................... 1,074,567 $ 19.0728
Options Granted........................................................ 2,243,535 $ 26.3112
Options Exercised(1)................................................... (287,591) $ 15.6576
Option Withheld for Taxes.............................................. (6,854)
Options Canceled....................................................... (78,003)
Outstanding at December 31, 1998......................................... 2,945,654 $ 24.8668
</TABLE>
<TABLE>
<CAPTION>
NUMBER RANGE OF EXERCISE
OF SHARES PRICES
--------- ---------------
<S> <C> <C>
Exercisable at:
December 31, 1998...................................................... 531,855 $ 7.00-35.18
December 31, 1997...................................................... 645,304 $ 7.00-35.18
December 31, 1996...................................................... 280,270 $ 17.75-23.25
</TABLE>
- ----------
(1) Effective upon the Merger, each holder of an unexpired Resources stock
option, whether or not then exercisable, was entitled to elect to either
(i) have all or any portion of their Resources stock options canceled and
"cashed out" or (ii) have all or any portion of their Resources stock
options converted to the Company's stock options. There were 828,297
Resources stock options converted into 622,504 of the Company's stock
options at the Acquisition Date. Options exercised during 1998 and 1997
included approximately 210,000 and 277,000 shares, respectively, related to
Resources stock options which were converted at the Merger.
Effective January 1, 1996, the Company adopted SFAS No. 123, "Accounting
for Stock-Based Compensation" (SFAS No. 123). In accordance with SFAS No. 123,
the Company will continue to apply the existing rules contained in Accounting
Principles Opinion No. 25, "Accounting for Stock Issued to Employees," and
disclose the required pro forma effect on net income and earnings per share of
the fair value based method of accounting for stock compensation as required by
SFAS No. 123.
91
<PAGE> 96
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The following pro forma summary of the Company's consolidated results of
operations has been prepared as if the fair value based method of accounting for
employee stock compensation required by SFAS No. 123 had been applied:
<TABLE>
<CAPTION>
1998 1997 1996
---------- ---------- ----------
(THOUSANDS OF DOLLARS,
EXCEPT PER SHARE DATA)
<S> <C> <C> <C>
Net Income (Loss) available for common stock as reported.............. $ (141,482) $ 420,948 $ 404,944
SFAS No. 123 effect................................................... (6,383) (2,374) (1,098)
---------- ---------- ----------
Pro forma Net Income (Loss) available for common stock................ $ (147,865) $ 418,574 $ 403,846
========== ========== ==========
Pro forma Basic Earnings per Common Share............................. $ (.50) $ 1.66 $ 1.66
Pro forma Diluted Earnings per Common Share........................... (.52) 1.65 1.66
</TABLE>
The fair value of options granted during 1996, 1997 and 1998 was calculated
using the Black-Scholes model. The significant assumptions incorporated in the
Black-Scholes model in estimating the fair value of the options include (i) an
interest rate of 5.65% for 1996, 6.58% for 1997 and 5.65% for 1998 that
represents the interest rate on a U.S. Treasury security with a maturity date
corresponding with the option term, (ii) an option term of ten years, (iii)
volatility of 15.713% for 1996, 22.06% for 1997 and 24.01% for 1998 calculated
using daily stock prices for the period prior to the grant date and (iv)
expected common dividends of $1.50 per share representing annualized dividends
at the date of grant.
(b) Pension.
The Company has a noncontributory retirement plan which covers the
employees of the Company and its subsidiaries other than Resources. Resources
has two noncontributory retirement plans: (i) the plan which covers the
employees of Resources other than Minnegasco employees and (ii) the plan which
covers Minnegasco employees. The plans provide retirement benefits based on
years of service and compensation. The Company's and Resources' funding policy
is to contribute amounts annually in accordance with applicable regulations in
order to achieve adequate funding of projected benefit obligations. The assets
of the plans consist principally of common stocks and high-quality,
interest-bearing obligations. The net periodic pension costs, prepaid pension
costs and benefit obligation have been determined separately for each plan.
In 1998, the Company adopted SFAS No. 132, "Employers' Disclosures about
Pensions and Other Postretirement Benefits" (SFAS No. 132). SFAS No. 132 revises
employers' disclosures about pension and other postretirement benefit plans. It
does not change the measurement or recognition of those plans.
Net pension cost for the Company attributable to continuing operations
includes the following components:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------------
1998 1997 1996
---------- ---------- -----------
(THOUSAND OF DOLLARS)
<S> <C> <C> <C>
Service cost-- benefits earned during the period..................... $ 33,436 $ 26,848 $ 24,392
Interest cost on projected benefit obligation......................... 85,132 67,641 51,560
Expected (return) loss on plan assets................................. (121,196) (86,372) (57,818)
Net amortization...................................................... 6 6 6
---------- ---------- -----------
Net pension cost............................................ (2,622) 8,123 18,140
Transfer of obligation to STPNOC...................................... (6,077)
SFAS No. 88-- curtailment expense..................................... 12,947 12,698
---------- ---------- -----------
Total pension cost.......................................... $ (2,622) $ 14,993 $ 30,838
========== ========== ===========
</TABLE>
92
<PAGE> 97
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Following are reconciliations of the Company's beginning and ending
balances of its retirement plan benefit obligation, plan assets and funded
status for 1998 and 1997.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------
1998 1997
------------- -------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of year.................................... $ 1,246,582 $ 756,597
Service cost............................................................. 33,436 26,848
Interest cost............................................................ 85,132 67,641
Benefits paid............................................................ (69,182) (71,924)
Plan amendments.......................................................... (161,326)
Acquisitions and divestitures............................................ 439,545
Actuarial (gain) loss.................................................... 254,802 27,875
------------- -------------
Benefit obligation, end of year.......................................... $ 1,389,444 $ 1,246,582
------------- -------------
CHANGE IN PLAN ASSETS
Plan asset, beginning of year............................................ 1,304,023 675,401
Benefits paid............................................................ (69,182) (71,924)
Employer contributions................................................... 47,406 41,332
Acquisitions and divestitures............................................ 534,692
Actual investment return................................................. 147,635 124,522
------------- -------------
Plan assets, end of year................................................. $ 1,429,882 $ 1,304,023
------------- -------------
RECONCILIATION OF FUNDED STATUS
Funded status............................................................ 40,438 57,441
Unrecognized transition (asset) or obligation............................ (7,205) (9,008)
Unrecognized prior service cost.......................................... (148,400) 14,734
Unrecognized actuarial (gain) loss....................................... 240,864 12,501
------------- -------------
Net amount recognized.................................................... $ 125,697 $ 75,668
============= =============
</TABLE>
Amounts recognized in the Company's Consolidated Balance Sheet consist of:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------
1998 1997
------------- -------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
Prepaid benefit cost........................................................ $ 125,697 $ 95,815
Accrued benefit liability................................................... (20,147)
------------- -------------
Net amount recognized....................................................... $ 125,697 $ 75,668
============= =============
</TABLE>
The benefit obligation was determined using an assumed discount rate of
6.50% in 1998 and 7.25% in 1997 and 1996. A long-term annual rate of
compensation increase ranging from 3.5% to 5.5% in 1998 and 4% to 6% in 1997 and
1996 was assumed for both the Company and Resources plans, respectively. The
assumed long-term rate of return on plan assets was 10% in 1998 and 9.5% in 1997
and 1996 (10% for the Resources plans in 1997). The transitional asset at
January 1, 1986, is being recognized over approximately 17 years, and the prior
service cost is being recognized over approximately 15 years for the Company's
plan. The unrecognized transitional asset, prior service cost and net (gain) or
loss related to the Resources' plans were recognized at the Acquisition Date.
Pursuant to SFAS No. 71, the Company's deferred costs associated with the
increases in its benefit obligations related to a 1995 early retirement
incentive program were amortized through the period ending December 31, 1997. In
1997 and 1996, the Company amortized $12.9 million and $12.7 million,
respectively, of those costs as a
93
<PAGE> 98
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
curtailment under SFAS No. 88, "Employers' Accounting for Settlements and
Curtailments of Defined Benefit Pension Plans and for Termination Benefits"
(SFAS No. 88), with regards to the Company's early retirement program.
In 1998, the Company's board of directors approved an amendment, effective
January 1, 1999, which converted the present value of the accrued benefits
under the existing pension plans into a cash balance pension plan. Under the
cash balance formula, each participant has an account, for recordkeeping
purposes only, to which credits are allocated annually based on a percentage of
the participant's pay. The applicable percentage is 4%.
The purpose of the plan change is to continue to provide uniform
retirement income benefits across all employee groups, which are competitive
both within the utility industry as well as with other companies within the
United States.
The Company will continue to reflect the costs of the pension plan
according to the provisions of SFAS No. 87, as amended by SFAS No. 132. As a
result of the January 1, 1999 amendment, which is reflected in the December 31,
1998 disclosure, the Company's benefit obligation declined $161 million. The
plan amendment had no impact on 1998 expense.
The actuarial loss is due to changes in certain actuarial assumptions.
(c) Savings Plan.
The Company has an employee savings plan that qualifies as cash or deferred
arrangements under Section 401(k) of the Internal Revenue Code of 1986, as
amended (IRC). Under the plan, participating employees may contribute a portion
of their compensation, pretax or after-tax, up to a maximum of 16% of
compensation limited by an annual deferral limit ($10,000 for calendar year
1998) prescribed by IRC Section 402(g) and the IRC Section 415 annual additions
limits. Through 1998, the Company matched 70% of the first 6% of each employee's
compensation contributed, subject to a vesting schedule which entitled the
employee to a percentage of the matching contributions depending on years of
service. Substantially all of the Company's match is invested in the Company's
common stock.
In October 1990, the Company amended its savings plan to add a leveraged
Employee Stock Ownership Plan (ESOP) component. The Company may use ESOP shares
to satisfy its obligation to make matching contributions under the savings plan.
Debt service on the ESOP loan is paid using all dividends on shares in the ESOP,
interest earnings on funds held in the ESOP and cash contributions by the
Company. Shares of the Company's common stock are released from the encumbrance
of the ESOP loan based on the proportion of debt service paid during the period.
As provided for under Statement of Position 93-6 (SOP 93-6), the Company
recognizes benefit expense for the ESOP equal to the fair value of the ESOP
shares committed to be released. In accordance with SOP 93-6, the Company
credits to unearned ESOP shares the original purchase price of ESOP shares
committed to be released to plan participants with the difference between the
fair value of the shares and the original purchase price recorded to common
stock. Dividends on allocated ESOP shares are recorded as a reduction to
retained earnings; dividends on unallocated ESOP shares are recorded as a
reduction of debt or accrued interest on the ESOP loan.
The Company's savings plan benefit expense attributable to operations was
$13.8 million, $18.4 million and $16.0 million in 1998, 1997 and 1996,
respectively.
The ESOP shares were as follows:
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------------------
1998 1997
-------------- --------------
<S> <C> <C>
Allocated shares transferred/distributed from the
Savings Plan(1)....................................... 1,916,508 1,920,406
Allocated shares........................................ 5,171,613 4,453,227
Unearned shares......................................... 11,674,063 12,388,551
-------------- --------------
Total original ESOP shares......................... 18,762,184 18,762,184
============== ==============
Fair value of unearned ESOP shares...................... $ 374,270,460 $ 331,393,739
</TABLE>
- ----------
(1) 1,102,203 allocated shares transferred are related to shares transferred to
STPNOC in December 1997.
Resources has an employee savings plan (Resources Savings Plan) which
covers substantially all employees other than Reliant Energy Minnegasco
employees. Under the terms of the Resources Savings Plan, employees may
contribute up to 12% of total compensation, which contributions up to 6% are
matched by the Company. The Reliant Energy Minnegasco employees are covered by a
savings plan, the terms of which are somewhat similar to the Resources Savings
Plan. Employer contributions related to the Resources and Reliant Energy
Minnegasco Savings Plan were $10.8 million and $3.7 million in 1998 and 1997
since the Acquisition Date, respectively.
94
<PAGE> 99
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(d) Postretirement Benefits.
The Company and Resources record the liability for post-retirement benefit
plans other than pensions (primarily health care) under SFAS No. 106,
"Employer's Accounting for Postretirement Benefits Other Than Pensions" (SFAS
No. 106). The Company is amortizing over a 22 year period approximately $213
million to cover the "transition cost" of adopting SFAS No. 106 (i.e., the
Company's liability for postretirement benefits payable with respect to employee
service years accrued prior to the adoption of SFAS No. 106). The unrecognized
transitional asset and net (gain) loss related to the Resources plans were
recognized at the Acquisition Date.
As provided in the 1995 Rate Case Settlement, Electric Operations is
required to fund during each year in an irrevocable external trust approximately
$22 million of postretirement benefit costs which are included in its rates.
Reliant Energy Minnegasco is required to fund postretirement benefit costs for
the amount included in its rates. The Company and Resources, excluding Electric
Operations and Reliant Energy Minnegasco, will continue funding their
postretirement benefits on a pay-as-you-go basis.
Following are reconciliations of the Company's beginning and ending
balances of its postretirement benefit plans benefit obligation, plan assets and
funded status for 1998 and 1997.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------
1998 1997
------------- -------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of year.................... $ 269,531 $ 144,275
Service cost............................................. 8,060 8,927
Interest cost............................................ 17,270 14,176
Benefits paid............................................ (20,662) (11,963)
Participant contributions................................ 2,960 1,591
Plan amendments.......................................... 98,918
Acquisitions............................................. 115,721
Divestitures............................................. (10,277)
Actuarial (gain) loss.................................... 33,734 7,081
------------- -------------
Benefit obligation, end of year.......................... $ 409,811 $ 269,531
------------- -------------
CHANGE IN PLAN ASSETS
Plan asset, beginning of year............................ $ 56,340 $ 38,493
Benefits paid............................................ (20,662) (11,963)
Employer contributions................................... 32,889 18,440
Participant contributions................................ 2,960 1,591
Acquisitions............................................. 2,909
Divestitures............................................. (6,000)
Actual investment return................................. 12,541 12,870
------------- -------------
Plan assets, end of year................................. $ 84,068 $ 56,340
------------- -------------
RECONCILIATION OF FUNDED STATUS
Funded status............................................ $ (325,743) $ (213,191)
Unrecognized transition (asset) or obligation............ 144,046 153,175
Unrecognized prior service cost.......................... 98,918
Unrecognized actuarial (gain) loss....................... (61,530) (94,531)
------------- -------------
Net amount recognized at end of year..................... $ (144,309) $ (154,547)
============= =============
</TABLE>
95
<PAGE> 100
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The assumed health care cost trend rates used in measuring the
postretirement benefit obligation in 1998 are as follows:
<TABLE>
<S> <C>
Medical -- under 65......................................... 6.0%
Medical -- 65 and over...................................... 6.7%
</TABLE>
The assumed health care rates gradually decline to 5.4% for both medical
categories by 2001. The accumulated postretirement benefit obligation was
determined using an assumed discount rate of 6.5% for 1998 and 7.25% for 1997. A
long-term annual rate of compensation increase ranging from 3.5% to 5.5% and
4.0% to 6.0% was assumed in 1998 and 1997, respectively. The assumed long-term
rate of return on plan assets was 10% in 1998 and 9.5% in 1997.
If the health care cost trend rate assumptions were increased by 1%, the
accumulated postretirement benefit obligation as of December 31, 1998 would be
increased by approximately 4.7%. The annual effect of the 1% increase on the
total of the service and interest costs would be an increase of approximately
5.1%. If the healthcare cost trend rate assumptions were decreased by 1%, the
accumulated postretirement benefit obligation as of December 31, 1998 would be
decreased by approximately 4.3%. The annual effect of the 1% decrease on the
total of the service and interest costs would be a decrease of 4.6%.
In 1998, the Company's board of directors approved an amendment, effective
January 1, 1999, which created an account balance based on credited service at
December 31, 1998. Under the new plan, each participant has an account, for
recordkeeping purposes only, to which a $750 credit is allocated annually. This
account balance vests after 5 years of service after age 50. At retirement the
account balance can be used to purchase medical benefits. It may not be taken
as cash.
The purpose of the plan change is to continue to provide uniform retiree
medical benefits across all employee groups, which are competitive both within
the utility industry as well as with other companies within the United States.
The Company will continue to reflect the costs of the retiree medical plan
according to the provisions of SFAS No. 106 as amended by SFAS No. 132. As a
result of the January 1, 1999 amendment, which is reflected in the December 31,
1998 disclosure, the Company's benefit obligation increased $99 million. The
plan amendment had no impact on 1998 expense.
The actuarial loss is due to changes in certain actuarial assumptions.
(e) Postemployment Benefits.
The Company records postemployment benefits based on SFAS No. 112,
"Employer's Accounting for Postemployment Benefits," which requires the
recognition of a liability for benefits provided to former or inactive
employees, their beneficiaries and covered dependents, after employment but
before retirement (primarily health care and life insurance benefits for
participants in the long-term disability plan). Net postemployment benefit costs
were not material in 1998, 1997 and 1996.
(11) INCOME TAXES
The Company records income taxes under SFAS No. 109, "Accounting for Income
Taxes" (SFAS No. 109), which, among other things, (i) requires that the
liability method be used in computing deferred taxes on all temporary
differences between book and tax bases of assets other than nondeductible
goodwill; (ii) requires that deferred tax liabilities and assets be adjusted for
an enacted change in tax laws or rates; and (iii) prohibits net-of-tax
accounting and reporting. SFAS No. 109 requires that regulated enterprises
recognize such adjustments as regulatory assets or liabilities if it is probable
that such amounts will be recovered from or returned to customers in future
rates.
The Company's current and deferred components of income tax expense
(benefit) are as follows:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------------
1998 1997 1996
------------ ------------ ------------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C>
Current.................................... $ 439,322 $ 199,011 $ 150,658
Deferred .................................. (469,754) 7,363 49,507
------------ ------------ ------------
Income taxes............................... $ (30,432) $ 206,374 $ 200,165
============ ============ ============
</TABLE>
96
<PAGE> 101
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The Company's effective income tax rates are lower than statutory corporate
rates for each year as follows:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------------
1998 1997 1996
----------- ----------- -----------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C>
Income (loss) before income taxes.................................... $ (171,524) $ 627,484 $ 605,109
Preferred dividends of subsidiary.................................... 2,255 22,563
----------- ----------- -----------
Total........................................................... (171,524) 629,739 627,672
Statutory rate....................................................... 35% 35% 35%
----------- ----------- -----------
Income taxes at statutory rate....................................... (60,033) 220,409 219,685
----------- ----------- -----------
Net addition (reduction) in taxes resulting from:
State income taxes, net of federal income tax benefit............. 16,853 (9)
Amortization of investment tax credit............................. (20,123) (19,777) (18,404)
Excess deferred taxes............................................. (4,011) (5,570) (4,331)
Difference between book and tax depreciation for which deferred
taxes have not been normalized.................................. 37,069 27,466 22,638
Equity dividend exclusion......................................... (980) (5,075) (10,194)
Equity income - foreign affiliates................................ (23,241) (17,011) (5,936)
Goodwill.......................................................... 18,049 7,242
Other - net....................................................... 5,985 (1,301) (3,293)
----------- ----------- -----------
Total........................................................... 29,601 (14,035) (19,520)
----------- ----------- -----------
Income taxes......................................................... $ (30,432) $ 206,374 $ 200,165
=========== =========== ===========
Effective rate....................................................... 17.7% 32.8% 31.9%
</TABLE>
97
<PAGE> 102
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Following are the Company's tax effects of temporary differences
attributable to continuing operations resulting in deferred tax assets and
liabilities:
<TABLE>
<CAPTION>
-----------------------------
DECEMBER 31,
-----------------------------
1998 1997
------------ ------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
Deferred Tax Assets:
Alternative minimum tax credit carryforwards.................................... $ 39,893 $ 60,669
Employee benefits............................................................... 154,746 145,794
Disallowed plant cost - net..................................................... 56,219 22,378
ACES............................................................................ 454,165 42,491
State operating loss carryforwards.............................................. 23,178 29,515
Deferred state income taxes..................................................... 14,455 14,460
Other........................................................................... 92,659 69,235
Valuation allowance............................................................. (8,591) (6,353)
------------ ------------
Total deferred tax assets - net.............................................. $ 826,724 378,189
------------ ------------
Deferred Tax Liabilities:
Depreciation.................................................................... $ 2,106,860 $ 2,115,717
Deferred plant costs - net...................................................... 147,278 186,472
Regulatory tax asset - net ..................................................... 418,339 356,509
Capitalized taxes, employee benefits and removal costs.......................... 60,099 46,584
Gain on sale of cable television subsidiary..................................... 222,942 222,942
Deferred state income taxes..................................................... 70,000 70,000
Deferred gas costs.............................................................. 13,663 34,113
Loss on reacquired debt......................................................... 44,077 39,503
Other........................................................................... 107,502 99,130
------------ ------------
Total deferred tax liabilities............................................... 3,190,760 3,170,970
------------ ------------
Accumulated deferred income taxes - net................................. $ 2,364,036 $ 2,792,781
============ ============
</TABLE>
Tax Refund Case. In July 1990, the Company paid approximately $104.5
million to the Internal Revenue Service (IRS) following an IRS audit of Former
Parent's 1983 and 1984 federal income tax returns. In November 1991, Former
Parent filed a refund suit in the U.S. Court of Federal Claims seeking the
return of $52.1 million of tax and $36.3 million of accrued interest, plus
interest on both of those amounts accruing after July 1990. The major contested
issue in the refund case involved the IRS allegation that certain amounts
related to the over-recovery of fuel costs should have been included as taxable
income in 1983 and 1984 even though the Company had an obligation to refund the
over-recoveries to its ratepayers.
In September 1997, the United States Court of Appeals upheld a lower court
ruling that the Company (as successor corporation to Former Parent) was due a
refund of federal income taxes assessed on fuel over-recoveries during 1983 and
1984 that subsequently were refunded to Electric Operations' customers.
In February 1998, the Company received a refund of approximately $142
million in taxes and interest paid by Former Parent in July 1990, including
interest accrued since 1990 in the amount of approximately $57 million. After
giving effect to the Company's deferred recognition of the 1990 tax payment and
payment of federal income taxes due on the accrued interest on the refund, the
refund had the effect of increasing the Company's earnings in the fourth quarter
of 1997 by $37 million (after-tax).
Tax Attribute Carryforwards. At December 31, 1998, Resources has
approximately $368 million of state net operating losses available to offset
future state taxable income through the year 2013. In addition, Resources has
approximately $33 million of federal alternative minimum tax credits which are
available to reduce future federal income taxes payable, if any, over an
indefinite period (although not below the tentative minimum tax otherwise due
98
<PAGE> 103
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
in any year), and approximately $2.6 million of state alternative minimum tax
credits which are available to reduce future state income taxes payable, if any,
through the year 2001. The valuation allowance reflects a net increase of $2.3
million in 1998. This net increase results from a reassessment of Resources'
usage of state tax attributes, including the future ability to use state net
operating loss and alternative minimum tax credit carryforwards offset by
changes in valuation allowances provided for expiring state net operating loss
carryforwards.
(12) COMMITMENTS AND CONTINGENCIES
(a) Commitments.
The Company has various commitments for capital expenditures, fuel,
purchased power, cooling water and operating leases. Commitments in connection
with Electric Operations' capital program are generally revocable by the
Company, subject to reimbursement to manufacturers for expenditures incurred or
other cancellation penalties. The Company's and its subsidiaries' other
commitments have various quantity requirements and durations. However, if these
requirements could not be met, various alternatives are available to mitigate
the cost associated with the contracts' commitments.
(b) Fuel and Purchased Power.
The Company is a party to several long-term coal, lignite and natural gas
contracts which have various quantity requirements and durations. Minimum
payment obligations for coal and transportation agreements are approximately
$210 million in 1999, $187 million in 2000 and $188 million in 2001.
Additionally, minimum payment obligations for lignite mining and lease
agreements are approximately $9 million for 1999, $10 million for 2000 and $10
million for 2001. Minimum payment obligations for both natural gas purchase and
storage contracts associated with Electric Operations are approximately $10
million in 1999, $9 million in 2000 and $9 million in 2001.
The Company also has commitments to purchase firm capacity from two
cogenerators totaling approximately $22 million in both 1999 and 2000. Texas
Utility Commission rules currently allow recovery of these costs through
Electric Operations' base rates for electric service and additionally authorize
the Company to charge or credit customers through a purchased power cost
recovery factor for any variation in actual purchased power costs from the cost
utilized to determine its base rates. In the event that the Texas Utility
Commission, at some future date, does not allow recovery through rates of any
amount of purchased power payments, these two firm capacity contracts contain
provisions allowing the Company to suspend or reduce payments and seek repayment
for amounts disallowed. Both of these firm capacity contracts have initial terms
ending March 31, 2005.
(c) Operations Agreement with City of San Antonio.
As part of the 1996 settlement of certain litigation claims asserted by the
City of San Antonio with respect to the South Texas Project, the Company entered
into a 10-year joint operations agreement under which the Company and the City
of San Antonio, acting through the City Public Service Board of San Antonio
(CPS), share savings resulting from the joint dispatching of their respective
generating assets in order to take advantage of each system's lower cost
resources. Under the terms of the joint operations agreement entered into
between CPS and Electric Operations, the Company has guaranteed CPS minimum
annual savings of $10 million and a minimum cumulative savings of $150 million
over the 10-year term of the agreement. Based on current forecasts and other
assumptions regarding the combined operation of the two generating systems, the
Company anticipates that the savings resulting from joint operations will equal
or exceed the minimum savings guaranteed under the joint operating agreement. In
1996, savings generated for CPS' account for a partial year of joint operations
were approximately $14 million. In 1997 and 1998, savings generated for CPS'
account for a full year of operation were approximately $22 million and $14
million, respectively.
99
<PAGE> 104
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(d) Transportation Agreement.
Resources had an agreement (ANR Agreement) with ANR Pipeline Company (ANR)
which contemplated that Resources would transfer to ANR an interest in certain
of Resources' pipeline and related assets. The interest represented capacity of
250 Mmcf/day. Under the ANR Agreement, an ANR affiliate advanced $125 million to
Resources. Subsequently, the parties restructured the ANR Agreement and
Resources refunded in 1995 and 1993, respectively, $50 million and $34 million
to ANR or an affiliate. Resources recorded $41 million as a liability reflecting
ANR's or its affiliates' use of 130 Mmcf/day of capacity in certain of
Resources' transportation facilities. The level of transportation will decline
to 100 Mmcf/day in the year 2003 with a refund of $5 million to an ANR
affiliate. The ANR Agreement will terminate in 2005 with a refund of the
remaining balance.
(e) Lease Commitments.
The following table sets forth certain information concerning the Company's
obligations under non-cancelable long-term operating leases:
Minimum Lease Commitments at December 31, 1998 (1)
(Millions of Dollars)
<TABLE>
<S> <C>
1999.................................................... $ 20
2000.................................................... 16
2001.................................................... 15
2002.................................................... 11
2003.................................................... 10
2004 and beyond......................................... 66
---------
Total......................................... $ 138
---------
</TABLE>
- ----------
(1) Principally consisting of rental agreements for building space and data
processing equipment and vehicles (including major work equipment).
Resources has a master leasing agreement which provides for the lease of
vehicles, construction equipment, office furniture, data processing equipment
and other property. For accounting purposes, the lease is treated as an
operating lease. Resources does not expect to lease additional property under
this lease agreement.
Total rental expense for all Resources' leases was approximately $25
million in 1998. Total rental expense for all leases in 1997 since the
Acquisition Date was approximately $15 million.
(f) Letters of Credit.
At December 31, 1998, the Company and Resources had letters of credit
incidental with their ordinary business operations totaling approximately $34
million under which they are obligated to reimburse drawings, if any.
(g) Indemnity Provisions.
At December 31, 1998, Resources had a $5.8 million accounting reserve on
the Company's Consolidated Balance Sheet in Other Deferred Credits for possible
indemnity claims asserted in connection with its disposition of Resources'
former subsidiaries or divisions, including the sale of (i) Louisiana Intrastate
Gas Corporation, a former Resources subsidiary engaged in the intrastate
pipeline and liquids extraction business; (ii) Arkla Exploration Company, a
former Resources subsidiary engaged in oil and gas exploration and production
activities; and (iii) Dyco Petroleum Company, a former Resources subsidiary
engaged in oil and gas exploration and production.
100
<PAGE> 105
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(h) Environmental Matters.
The Company is a defendant in litigation arising out of the environmental
remediation of a site in Corpus Christi, Texas. The litigation was instituted in
1985 by adjacent landowners. The litigation is pending before the United States
District Court for the Southern District of Texas, Corpus Christi Division. The
site was operated by third parties as a metals reclaiming operation. Although
the Company neither operated nor owned the site, certain transformers and other
equipment originally sold by the Company may have been delivered to the site by
third parties. The Company and others have remediated the site pursuant to a
plan approved by appropriate state agencies and a federal court. To date, the
Company has recovered or has commitments to recover from other responsible
parties $2.2 million of the more than $3 million it has spent on remediation.
In 1992, the United States Environmental Protection Agency (EPA) (i)
identified the Company, along with several other parties, as "potentially
responsible parties" (PRP) under the Comprehensive Environmental Response,
Compensation and Liability Act (CERCLA) for the costs of cleaning up a site
located adjacent to one of the Company's transmission lines in La Marque, Texas
and (ii) issued an administrative order for the remediation of the site. The
Company believes that the EPA took this action solely on the basis of
information indicating that the Company in the 1950s acquired record title to a
portion of the land on which the site is located. The Company does not believe
that it now or previously has held any ownership interest in the property
covered by the order and has obtained a judgement to that effect from a court in
Galveston County, Texas. Based on this judgement and other defenses that the
Company believes to be meritorious, the Company has elected not to adhere to the
EPA's administrative order, even though the Company understands that other PRPs
are proceeding with site remediation. To date, neither the EPA nor any other PRP
has instituted an action against the Company for any share of the remediation
costs for the site. However, if the Company was determined to be a responsible
party, the Company could be jointly and severally liable along with the other
PRPs for the aggregate remediation costs of the site (which the Company
currently estimates to be approximately $80 million in the aggregate) and could
be assessed substantial fines and damage claims. Although the ultimate outcome
of this matter cannot currently be predicted at this time, the Company does not
believe that this case will have a material adverse effect on the Company's
financial condition, liquidity or results of operations.
From time to time the Company and its subsidiaries have received notices
from regulatory authorities or others regarding their status as potential PRPs
in connection with sites found to require remediation due to the presence of
environmental contaminants. In addition, the Company has been named as defendant
in litigation related to such sites and in recent years has been named, along
with numerous others, as a defendant in several lawsuits filed by a large number
of individuals who claim injury due to exposure to asbestos while working at
sites along the Texas Gulf Coast. Most of these claimants have been workers who
participated in construction of various industrial facilities, including power
plants, and some of the claimants have worked at locations owned by the Company.
The Company anticipates that additional claims like those received may be
asserted in the future and intends to continue its practice of vigorously
contesting claims which it does not consider to have merit. Although their
ultimate outcome cannot be predicted at this time, the Company does not believe,
based on its experience to date, that these matters, either individually or in
the aggregate, will have a material adverse effect on the Company's financial
position, results of operation or cash flows.
(i) Other.
Electric Operations' service area is heavily dependent on oil, gas, refined
products, petrochemicals and related businesses. Significant adverse events
affecting these industries would negatively affect the revenues of the Company.
The Company and Resources are involved in legal, tax and regulatory
proceedings before various courts, regulatory commissions and governmental
agencies regarding matters arising in the ordinary course of business, some of
which involve substantial amounts. The Company's management regularly analyzes
current information and, as necessary, provides accruals for probable
liabilities on the eventual disposition of these matters. The Company's
management believes that the effect on the Company's and Resources' respective
financial statements, if any, from the disposition of these matters will not be
material.
101
<PAGE> 106
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In February 1996, the cities of Wharton, Galveston and Pasadena filed suit,
for themselves and a proposed class, against the Company and Houston Industries
Finance Inc. (formerly a wholly owned subsidiary of the Company) citing
underpayment of municipal franchise fees. The plaintiffs claim, among other
things, that from 1957 to the present, franchise fees should have been paid on
sales taxes collected by Electric Operations on receipts from sales to other
utilities and on receipts from services as well as sales of electricity.
Plaintiffs advance their claims notwithstanding their failure to notice such
claims over the previous four decades. Because all of the franchise ordinances
affecting Electric Operations expressly impose fees only on receipts from sales
of electricity for consumption within a city, the Company regards plaintiffs'
allegations as spurious and is vigorously contesting the matter. The plaintiffs'
pleadings assert that their damages exceed $250 million. The District Court for
Harris County has granted a partial summary judgment in favor of the Company
dismissing all claims for franchise fees based on sales tax collections. Other
motions for partial summary judgment remain pending. Although the Company
believes the claims to be without merit, the Company cannot at this time
estimate a range of possible loss, if any, from the lawsuit, nor can any
assurance be given as to its ultimate outcome.
(13) ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------------------------------------
1998 1997
----------------------------- --------------------------
CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE
------------ ----------- ----------- -----------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Financial Assets:
Company:
Investment in Time Warner securities.......... $ 990,000 $ 2,843,585 $ 990,000 $ 1,420,360
Resources:
Energy Derivatives - non-trading.............. -- -- 9,399 13,060
Financial Liabilities:
Company:
First mortgage bonds.......................... 2,036,284 2,177,434 2,495,459 2,651,260
Pollution control revenue bonds............... 581,385 582,069 123,000 123,000
Debentures.................................... 349,468 378,825 349,283 379,490
ACES.......................................... 2,349,997 2,436,949 1,173,786 1,307,247
Trust preferred and capital securities........ 341,075 366,182 340,882 366,220
Interest rate swaps........................... 109 3,160 65 1,679
Resources:
Long-term debt................................ 1,513,289 1,746,641 1,148,848 1,147,344
Trust preferred securities.................... 1,157 1,467 21,290 24,569
Energy Derivatives - non-trading.............. -- 8,166 -- --
Interest rate swaps........................... -- -- -- 755
</TABLE>
The fair values of cash and short-term investments, investment in the
Company's nuclear decommissioning trust, short-term and other notes payable and
floating rate debt of Reliant Energy International are estimated to be
equivalent to carrying amounts. The remaining fair values have been determined
using quoted market prices of the same or similar securities when available or
other estimation techniques.
The fair value of financial instruments included in the trading operations
of Reliant Energy Services are marked-to-market at December 31, 1998 (see Note
2). Therefore, they are stated at fair value and are excluded from the table.
102
<PAGE> 107
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(14) UNAUDITED QUARTERLY INFORMATION
The following unaudited quarterly financial information includes, in the
opinion of management, all adjustments (which comprise only normal recurring
accruals) necessary for a fair presentation. Quarterly results are not
necessarily indicative of a full year's operations because of seasonality and
other factors, including rate increases and variations in operating expense
patterns. Results of operations of the Resources businesses, purchased in 1997,
are included beginning on the Acquisition Date.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, 1998
----------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
------------ ----------- ------------ ------------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C>
Revenues (1)........................................... $ 2,631,322 $ 2,736,626 $ 3,465,487 $ 2,655,029
Operating Income (1)................................... 282,892 455,809 512,955 225,732
Net Income (Loss) available for common stock (1)....... (30,115) 41,484 251,709 (404,560)
Basic Earnings (Loss) per Common Share (2)............. (.11) .15 .89 (1.42)
Diluted Earnings (Loss) per Common Share (2)........... (.11) .15 .88 (1.42)
</TABLE>
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, 1997
----------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
------------ ----------- ------------ ------------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C>
Revenues............................................... $ 878,101 $ 1,064,448 $ 2,158,054 $ 2,777,622
Operating Income....................................... 156,216 247,172 462,716 198,396
Net Income (Loss) available for common stock........... 59,620 121,463 243,898 (4,033)
Basic Earnings (Loss) per Common Share (2)............. .26 .52 .93 (.01)
Diluted earnings (Loss) per Common Share (2)........... .26 .52 .92 (.01)
</TABLE>
- ----------
(1) Includes retroactive adjustment for change in accounting for energy price
risk management and trading activities of Reliant Energy Services to
mark-to-market accounting for the first, second and third quarters of 1998.
(See Note 1(r))
(2) Quarterly earnings per common share are based on the weighted average
number of shares outstanding during the quarter, and the sum of the
quarters may not equal annual earnings per common share.
(15) REPORTABLE SEGMENTS
Effective January 1, 1998, the Company adopted SFAS No. 131, "Disclosures
about Segments of an Enterprise and Related Information" (SFAS No. 131). The
Company's determination of reportable segments considers the strategic operating
units under which the Company manages sales of various products and services to
wholesale or retail customers in differing regulatory environments. The
determination of reportable segments under SFAS No. 131 differs from that
required in prior years, therefore business segment information for 1997 and
1996 has been restated to comply with SFAS No. 131. Consistent with the purchase
accounting treatment for the Merger, financial information for Resources is
included in the segment disclosures only for periods beginning on the
Acquisition Date.
The accounting policies of the segments are the same as those described in
the summary of significant accounting policies except that certain executive
benefit costs have not been allocated to segments. The Company evaluates
performance based on operating income excluding certain corporate costs not
allocated to the segments. The Company accounts for intersegment sales as if the
sales were to third parties, that is, at current market prices.
In accordance with SFAS No. 131, the Company has identified the following
reportable segments: Electric Operations, Natural Gas Distribution, Interstate
Pipelines, Wholesale Energy and Marketing (Wholesale Energy), International and
Corporate. Electric Operations provides electric generation, transmission,
distribution and sales to
103
<PAGE> 108
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
customers. Natural Gas Distribution operations consist of natural gas sales to,
and natural gas transportation for, residential, commercial and industrial
customers. Interstate Pipelines conducts interstate natural gas pipeline
operations. Wholesale Energy is engaged in the acquisition, development and
operation of non-rate regulated power generation facilities as well as the
wholesale energy trading and marketing and natural gas gathering businesses.
International participates in the development and acquisition of foreign
independent power projects and the privatization of foreign generation and
distribution facilities. Corporate includes the Company's unregulated retail
electric services business, certain real estate holdings of the Company and
corporate costs.
Financial data for business segments, products and services and geographic
areas are as follows:
<TABLE>
<CAPTION>
ELECTRIC NATURAL GAS INTERSTATE WHOLESALE INTER- CORPORATE RECONCILING
OPERATIONS DISTRIBUTION PIPELINES ENERGY NATIONAL AND OTHER ELIMINATIONS CONSOLIDATED
---------- ---------- -------- ---------- -------- -------- ----------- ------------
(Thousands of Dollars)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
As of and for the Year Ended
December 31, 1998:
Revenues from external
customers...................... $4,350,275 $1,811,509 $126,988 $4,289,006 $258,945 $651,741 $11,488,464
Intersegment revenues.......... 1,167 155,508 167,152 97,181 $(421,008)
Depreciation and amortization.. 650,264 129,777 44,025 18,204 3,820 10,527 856,617
Operating income............... 1,013,979 137,955 128,328 59,170 181,707 (43,751) 1,477,388
Total assets................... 10,404,447 3,110,718 2,050,636 1,535,007 1,242,689 1,710,920 (915,895) 19,138,522
Equity investments in and
advances to unconsolidated
subsidiaries................... 42,252 1,009,348 1,051,600
Expenditures for additions to
long-lived assets.............. 433,474 161,735 59,358 365,512 435,077 28,077 1,483,233
As of and for the Year
Ended
December 31, 1997:
Revenues from external
customers...................... 4,251,243 892,064 49,655 1,288,357 92,028 304,878 6,878,225
Intersegment revenues.......... 505 58,678 76,301 34,853 (170,337)
Depreciation and amortization.. 568,541 51,883 19,088 2,633 3,470 6,260 651,875
Operating income............... 994,938 54,502 31,978 912 19,510 (37,340) 1,064,500
Total assets................... 10,540,849 3,073,525 2,031,879 777,638 869,485 1,749,916 (597,686) 18,445,606
Equity investments in and
advances to unconsolidated
subsidiaries................... 3,325 700,777 704,102
Expenditures for additions to
long-lived assets.............. 236,977 61,078 16,304 14,038 231,528 23,899 583,824
For the Year Ended
December 31, 1996:
Revenues from external
customers...................... 4,025,027 62,059 8,191 4,095,277
Depreciation and amortization.. 545,685 1,648 2,705 550,038
Operating income............... 997,147 2,339 (9,020) 990,466
Expenditures for additions to
long-lived assets.............. 317,532 495,379 19,989 832,900
</TABLE>
104
<PAGE> 109
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
RECONCILIATION OF OPERATING INCOME TO NET INCOME (IN THOUSANDS):
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------------------------------
1998 1997 1996
---------------- ---------------- ----------------
<S> <C> <C> <C>
Operating income...................................... $ 1,477,388 $ 1,064,500 $ 990,466
Interest income - IRS refund.......................... 981 56,269
Dividend income....................................... 41,250 41,340 41,610
Interest expense...................................... (513,905) (397,957) (309,980)
Unrealized loss on ACES............................... (1,176,211) (121,402)
Litigation settlements................................ (95,000)
Distribution on trust securities...................... (29,201) (26,230)
Preferred dividends of subsidiary..................... (2,255) (22,563)
Income tax benefit (expense).......................... 30,432 (206,374) (200,165)
Other income (expense)................................ 27,784 13,057 576
---------------- ---------------- ----------------
Net income (loss) available for Common Stock.......... $ (141,482) $ 420,948 $ 404,944
================ ================ ================
</TABLE>
REVENUES BY PRODUCTS AND SERVICES (IN THOUSANDS):
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------------------------------
1998 1997 1996
---------------- ---------------- ----------------
<S> <C> <C> <C>
Retail power sales.................................... $ 4,359,857 $ 4,253,893 $ 4,025,027
Retail gas sales...................................... 2,362,504 1,153,968
Wholesale energy and energy related sales............. 4,248,181 1,271,400
Gas transport......................................... 167,812 66,265
Equity income from international investments.......... 258,945 92,028 62,059
Energy products and services.......................... 91,165 40,671 8,191
---------------- ---------------- ----------------
Total................................................. $ 11,488,464 $ 6,878,225 $ 4,095,277
================ ================ ================
</TABLE>
REVENUES AND LONG-LIVED ASSETS BY GEOGRAPHIC AREAS (IN THOUSANDS):
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------------------------------
1998 1997 1996
---------------- ---------------- ----------------
<S> <C> <C> <C>
Revenues:
US.................................................... $ 11,229,519 $ 6,786,197 $ 4,033,218
International......................................... 258,945 92,028 62,059
---------------- ---------------- ----------------
Total................................................. $ 11,488,464 $ 6,878,225 $ 4,095,277
================ ================ ================
Long-lived assets:
US..................................................... $ 14,865,161 $ 14,691,820
International.......................................... 1,195,849 837,536
---------------- ----------------
Total.................................................. $ 16,061,010 $ 15,529,356
================ ================
</TABLE>
105
<PAGE> 110
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(16) SUBSEQUENT EVENTS
(a) Foreign Currency Devaluation.
In January 1999, the Brazilian real was devalued and allowed to float
against other major currencies. The Company expects to take a charge against
first quarter earnings as a result of the Brazilian devaluation. The charge will
reflect the Company's proportionate share of the impact of the devaluation on
foreign denominated debt of Brazilian corporations in which the Company holds an
equity interest. The amount of the charge will not be known until the end of the
first quarter.
At December 31, 1998, one U.S. dollar could be exchanged for 1.21 Brazilian
reais. Using the exchange rate of 2.06 reais/dollar in effect at the end of
February, and the average exchange rate in effect since the end of the year, the
Company estimates that its share of the after-tax charge that would be recorded
by the Brazilian companies in which it owns an interest would be approximately
$125 million.
(b) Trust Preferred Securities.
In February 1999, a Delaware statutory business trust (REI Trust I)
established by the Company issued $375 million of preferred securities to the
public and $11.6 million of common securities to the Company. The preferred
securities have a distribution rate of 7.20% payable quarterly in arrears, a
stated liquidation amount of $25 per preferred security and must be redeemed by
March 2048. REI Trust I used the proceeds from the sale of the preferred
securities and common securities to purchase $386.6 million aggregate principal
amount of subordinated debentures (REI Debentures) from the Company having an
interest rate corresponding to the distribution rate of the preferred securities
and a maturity date corresponding to the mandatory redemption date of the
preferred securities. Proceeds from the sale of the REI Debentures were used by
the Company for general corporate purposes, including the repayment of
short-term debt. REI Trust I is accounted for as a wholly owned consolidated
subsidiary of the Company. The REI Debentures are the REI Trust I's sole asset
and its entire operations. The Company has fully and unconditionally guaranteed,
on a subordinated basis, REI Trust I's obligations, including the payment of
distributions and all other payments due with respect to the preferred
securities. The preferred securities are mandatorily redeemable upon the
repayment of the REI Debentures at their stated maturity or earlier redemption.
Subject to certain limitations, the Company has the option of deferring payments
of interest on the REI Debentures held by REI Trust I. If and for as long as
interest payments on the REI Debentures have been deferred, or an event of
default under the indenture relating thereto has occurred and is continuing, the
Company may not pay dividends on its capital stock.
(c) Investment in Dutch Generating Company.
On March 10, 1999, the Company and N.V. Energieproduktiebedrijf UNA, a
Dutch electric generating company (UNA), announced their intent to enter into a
strategic partnership in the Netherlands. The transaction would involve the
initial acquisition by a subsidiary of the Company of 40% of the capital stock
of UNA for cash and a commitment to purchase the remaining 60% of the shares of
UNA for cash by December 31, 2006.
UNA is based in Utrecht and owns 3,400 megawatts of electric generating
capacity. The capacity is primarily fueled by natural gas.
The purchase price for the initial 40% interest will be approximately NLG
1.6 billion (approximately $ U.S. 840 million at an exchange rate of NLG 1.88
per U.S. dollar). Of this amount, the shareholders of UNA will receive a cash
payment of approximately NLG 675 million (approximately $ U.S. 360 million) in
exchange for shares representing 15% of the total capital stock of UNA. UNA will
receive (i) a cash payment of approximately NLG 21 million (approximately $ U.S.
11 million) and (ii) a five-year promissory note from a subsidiary of the
Company in the principal amount of approximately NLG 875 million (approximately
$ U.S. 465 million) for 25% of the total capital stock of the Company,
representing newly issued shares. The promissory note will bear interest at the
one-year EURIBOR rate, determined annually, and will be payable, subject to
certain conditions, on demand.
106
<PAGE> 111
HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Under the proposed terms of the acquisition, the shareholders of UNA would
agree to sell (i) an additional 12% of the total capital stock to the Company no
later than December 31, 2002 and (ii) the remaining 48% of the capital stock of
UNA no later than December 31, 2006. The purchase price for the remaining 60% of
the capital stock of UNA is approximately NLG 2.7 billion (approximately $U.S.
1.4 billion). The purchase obligations under the definitive agreements are in
Dutch guilders.
The Company expects to record its initial investment in UNA under the
equity method of accounting. The acquisition of the initial 40% of the capital
stock of UNA is subject to various approvals. It is anticipated that the closing
for this 40% interest will occur in June 1999.
107
<PAGE> 112
INDEPENDENT AUDITOR'S REPORT
Houston Industries Incorporated
d/b/a Reliant Energy, Incorporated:
We have audited the accompanying consolidated balance sheets and the
consolidated statements of capitalization of Houston Industries Incorporated
d/b/a Reliant Energy, Incorporated and its subsidiaries (the "Company") as of
December 31, 1998 and 1997, and the related statements of consolidated income,
consolidated retained earnings and comprehensive income, and consolidated cash
flows for each of the three years in the period ended December 31, 1998. Our
audits also included the Company's financial statement schedule listed in Item
14(a)(3). These financial statements and the financial statement schedule are
the responsibility of the Company's management. Our responsibility is to express
an opinion on these financial statements and the financial statement schedule
based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in
all material respects, the financial position of Reliant Energy, Incorporated
and its subsidiaries at December 31, 1998 and 1997, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1998 in conformity with generally accepted accounting principles.
Also, in our opinion, such financial statement schedule, when considered in
relation to the basic consolidated financial statements taken as a whole,
presents fairly in all material respects the information set forth therein.
DELOITTE & TOUCHE LLP
Houston, Texas
February 25, 1999
108
<PAGE> 113
ITEM 7. MANAGEMENT'S NARRATIVE ANALYSIS OF THE RESULTS OF OPERATIONS OF RELIANT
ENERGY RESOURCES CORP. AND CONSOLIDATED SUBSIDIARIES.
The following narrative and analysis should be read in combination with the
consolidated financial statements and notes (Resources' Consolidated Financial
Statements) of Reliant Energy Resources Corp. (formerly NorAm Energy Corp.)
(Resources) contained in Item 8 of the Form 10-K of Resources.
RELIANT ENERGY RESOURCES CORP.
On August 6, 1997 (Acquisition Date), the former parent corporation (Former
Parent) of Houston Industries Incorporated d/b/a Reliant Energy, Incorporated
(Reliant Energy) merged with and into Reliant Energy, and NorAm Energy Corp.
(Former Resources) merged with and into Resources. Effective upon the mergers
(collectively, the Merger), each outstanding share of common stock of Former
Parent was converted into one share of common stock (including associated
preference stock purchase rights) of Reliant Energy, and each outstanding share
of common stock of Former Resources was converted into the right to receive
$16.3051 cash or 0.74963 shares of common stock of Reliant Energy. The aggregate
consideration paid to Former Resources stockholders in connection with the
Merger consisted of $1.4 billion in cash and 47.8 million shares of Reliant
Energy's common stock valued at approximately $1.0 billion. The overall
transaction was valued at $4.0 billion consisting of $2.4 billion for Former
Resources' common stock and common stock equivalents and $1.6 billion of Former
Resources debt ($1.3 billion of which was long-term debt.)
The Merger was recorded under the purchase method of accounting with assets
and liabilities of Resources reflected at their estimated fair values as of the
Acquisition Date, resulting in a "new basis" of accounting. In Resources'
Consolidated Financial Statements, periods which reflect the new basis of
accounting are labeled as "Current Resources" and periods which do not reflect
the new basis of accounting are labeled as "Former Resources." Former Resources'
Statement of Consolidated Income for the seven months ended July 31, 1997
included certain adjustments from August 1, 1997 to the Acquisition Date for
pre-merger transactions.
Effective January 1, 1998, Resources adopted SFAS No. 131, "Disclosures
about Segments of an Enterprise and Related Information" (SFAS No. 131). Because
Resources is a wholly owned subsidiary of Reliant Energy, Resources'
determination of reportable segments considers the strategic operating units
under which Reliant Energy manages sales of various products and services to
wholesale or retail customers in differing regulatory environments. In
accordance with SFAS No. 131, Reliant Energy has identified the following
reportable segments: Electric Operations, Natural Gas Distribution, Interstate
Pipelines, Wholesale Energy Marketing and Generation (Wholesale Energy),
International and Corporate. Of these segments, the following operations are
conducted by Resources: Natural Gas Distribution, Interstate Pipelines,
Wholesale Energy (which includes the energy trading and marketing operations and
natural gas gathering operations of the Wholesale Energy segment but excludes
the operations of Reliant Energy Power Generation, Inc.) and Corporate
(excluding the impact of ACES).
Resources meets the conditions specified in General Instruction I to Form
10-K and is thereby permitted to use the reduced disclosure format for wholly
owned subsidiaries of reporting companies specified therein. Accordingly,
Resources has omitted from this Combined Annual Report the information called
for by Item 4 (submission of matters to a vote of security holders), Item 10
(directors and executive officers), Item 11 (executive compensation), Item 12
(security ownership of certain beneficial owners and management) and Item 13
(certain relationships and related transactions) of Form 10-K. In lieu of the
information called for by Item 6 (selected financial data) and Item 7
(management's discussion and analysis of financial condition and results of
operations) of Form 10-K, Resources has included the following Management's
Narrative Analysis of the Results of Operations to explain material changes in
the amount of revenue and expense items of Resources between 1998 and 1997.
Reference is hereby made to Item 1 (business), Item 2 (properties), Item 3
(legal proceedings), Item 5 (market for common equity and related stockholder
matters), Item 7A (quantitative and qualitative disclosures about market risk)
and Item 9 (changes in and disagreements with accountants on accounting and
financial disclosure) of this Combined Annual Report for additional information
regarding Resources required by the reduced disclosure format of General
Instruction I to Form 10-K.
CONSOLIDATED RESULTS OF OPERATIONS
Seasonality and Other Factors. Resources' results of operations are
affected by seasonal fluctuations in the demand for and, to a lesser
extent, the price of natural gas. Resources' results of operations are also
affected by,
109
<PAGE> 114
among other things, the actions of various federal and state governmental
authorities having jurisdiction over rates charged by Resources and its
subsidiaries, competition in Resources' various business operations, debt
service costs and income tax expense. For a discussion of certain other factors
that may affect Resources' future earnings see "Management's Discussion and
Analysis of Financial Condition and Results of Operations of the Company --
Certain Factors Affecting Future Earnings of the Company and its Subsidiaries
- -- Competition -- Other Operations"; "-- Impact of the Year 2000 Issue and Other
System Implementation Issues" and "-- Environmental Expenditures -- Mercury
Contamination" in Item 7 of Reliant Energy's Form 10-K.
Accounting Impact of the Merger. The Merger created a new basis of
accounting for Resources, resulting in new carrying values for certain of
Resources' assets, liabilities and equity commencing upon the Acquisition Date.
Resources' financial statements for periods subsequent to the Acquisition Date
are not comparable to prior periods because of the following purchase
accounting adjustments:
1. The impact of the amortization of newly-recognized goodwill ($39.4
million);
2. The amortization (to interest expense) of the revaluation of
long-term debt ($9.8 million);
3. The removal of the amortization (to operating expense) previously
associated with the pension and postretirement obligations ($2.1
million); and
4. The deferred income tax expense associated with these adjustments
($4.9 million).
Interest expense and related debt incurred by Reliant Energy to fund the cash
portion of the purchase consideration has not been pushed down to Resources and
its subsidiaries.
Because results of operations and other financial information for periods
before and after the Acquisition Date are not comparable, Resources is
presenting certain financial data on: (i) an actual basis for Resources for
1998 and 1997 and (ii) a pro forma basis for 1997 as if the Merger had taken
place at the beginning of the period. These results do not necessarily reflect
the results which would have been obtained if the Merger had actually occurred
on the dates indicated or the results that may be expected in the future.
The following table sets forth selected financial and operating data on an
actual and pro forma basis for the years ended December 31, 1998 and 1997,
followed by a discussion of significant variances in period-to-period results:
SELECTED FINANCIAL RESULTS:
<TABLE>
<CAPTION>
UNAUDITED
ACTUAL PRO FORMA (1)
--------------------------------------------- --------------
YEAR FIVE MONTHS SEVEN MONTHS YEAR ACTUAL TO
ENDED ENDED ENDED ENDED PRO FORMA
DECEMBER 31, DECEMBER 31, JULY 31, DECEMBER 31, PERCENTAGE
----------- ----------- ----------- ----------- CHANGE
1998 1997 1997 1997
----------- ----------- ----------- -----------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C> <C>
Operating Revenues .................. $ 6,758,412 $ 2,526,182 $ 3,313,591 $ 5,839,773 16%
Operating Expenses .................. 6,448,107 2,434,282 3,141,295 5,597,716 15%
Operating Income .................... 310,305 91,900 172,296 242,057 28%
Merger Transaction Costs (2) ........ 1,144 17,256
Consolidated ........................ 310,305 90,756 155,040 242,057 28%
Interest Expense, Net ............... 111,337 47,490 78,660 112,996 (1%)
Distributions on Subsidiary Trust
Securities .......................... 632 279 6,317 1,479 (57%)
Other (Income) and Deductions ....... (7,318) (2,243) (7,210) (9,453) (23%)
Income Tax Expense .................. 111,830 24,383 31,398 71,093 57%
Extraordinary (Gain), Less Taxes .... (237)
----------- ----------- ----------- -----------
Net Income ........................ $ 93,824 $ 20,847 $ 46,112 $ 65,942 42%
=========== =========== =========== ===========
</TABLE>
110
<PAGE> 115
- ----------
(1) Pro forma results reflect purchase accounting adjustments as if the Merger
had occurred on January 1, 1997.
(2) For expenses associated with the completion of the business combination
with Reliant Energy, see Note 1(o) to Resources' Consolidated Financial
Statements.
1998 Compared to 1997 (Actual). Resources' consolidated net income for 1998 was
$94 million compared to consolidated net income of $67 million in 1997. The
increase in net income for 1998 as compared to 1997 was due to increased
operating income from several business segments as discussed below, partially
offset by a decrease in operating income from Resources' Natural Gas
Distribution segment due to the effects of warm weather. Also contributing to
the increase in net income was a reduction in interest expense due to the
refinancing of debt and reduced interest expense due to debt fair value
devaluation at the time of the Merger.
Resources operating revenues for 1998 were $6.8 billion as compared to
$5.8 billion in 1997. The $900 million, or 16% increase was primarily
attributable to a $1.4 billion increase in wholesale trading revenue. Wholesale
trading revenue increased due to increased power and natural gas trading
volumes. The increase in trading revenues was offset by reduced revenues at
Resources' Natural Gas Distribution unit of approximately $400 million,
principally due to warmer weather.
Resources operating expenses for 1998 were $6.4 billion compared to $5.6
billion in 1997. The $800 million, or 16% increase was primarily due to
increased natural gas and purchased power expenses associated with increased
wholesale trading activities. The increase in operating expenses was offset by
decreased natural gas purchases at Resources' Natural Gas Distribution unit
because of lower volumes resulting from the warmer weather.
Operating income increased in 1998 by $65 million over 1997 due to improved
operating results at Interstate Pipelines, Corporate retail operations and
Wholesale Energy, partially offset by the unfavorable effects of warm weather on
the operations of Natural Gas Distribution. Operating income for 1997 included
approximately $18 million of merger-related costs that did not recur in 1998.
Improved results at Interstate Pipelines were due to continued cost control
initiatives and reduced benefits expenses, as well as the effects of a rate case
settlement and a dispute settlement which contributed to the increase in
operating income. In addition, margins at Wholesale Energy improved over margins
in 1997; however, this effect was partially offset by increased staffing
expenses to support increased sales and marketing efforts and an increase in
credit reserves. Improved results at Wholesale Energy were also due to the fact
that operating income in 1997 for Wholesale Energy was negatively impacted by
hedging losses associated with sales under peaking contracts and losses from the
sale of natural gas held in storage and unhedged in the first quarter of 1997
totaling $17 million.
1998 (Actual) Compared to 1997 (Pro Forma). Resources' consolidated net income
for 1998 was $94 million compared to pro forma net income of $66 million in
1997. The increase in earnings for 1998 as compared to pro forma 1997 was due
to increased operating income from several business segments, as discussed
below, offset by the effects of unfavorable weather at Resources' Natural Gas
Distribution unit. Also contributing to the increase in earnings is a
reduction in interest expense due to the refinancing of debt.
Resources operating revenues for 1998 were $6.8 billion compared to pro
forma operating revenues of $5.8 billion in 1997. The $919 million, or 16%
increase was primarily attributable to an $1.4 billion increase in wholesale
trading revenue. Wholesale trading revenue increased due to increased electric
and natural gas trading volumes. The increase in trading revenues was offset by
reduced revenues at Resources' Natural Gas Distribution unit of approximately
$400 million, principally due to warmer weather.
Resources operating expenses for 1998 were $6.4 billion compared to pro
forma operating expense of $5.6 billion in 1997. The $800 million, or 16%
increase was primarily due to increased natural gas and purchased power
expenses associated with increased wholesale trading activities. The increase
in operating expense was offset by decreased natural gas purchases at
Resources' Natural Gas Distribution unit because of lower volumes resulting
from warmer weather.
111
<PAGE> 116
Operating income increased in 1998 by $68 million over pro forma 1997 due
to improved operating results at Interstate Pipelines, Corporate retail
operations and Wholesale Energy, partially offset by the unfavorable effects of
Warm weather on the operations of Natural Gas Distribution. Improved results at
Interstate Pipelines are due to continued cost control initiatives and reduced
benefits expenses as well as the effects of a rate case settlement and a dispute
settlement. In addition, margins at Wholesale Energy improved over margins in
1997, however, this effect was partially offset by increased staffing expenses
to support increased sales and marketing efforts and an increase in credit
reserves at Wholesale Energy also contributed to the increase in operating
income. Operating income in 1997 for Wholesale Energy was negatively impacted by
hedging losses associated with sales under peaking contracts and losses from the
sale of natural gas held in storage and unhedged in the first quarter of 1997
totaling $17 million.
Resources estimates that its total direct cost of resolving the Year 2000
issues will be between $5 and $6 million. This estimate includes approximately
$3.4 million spent through year-end 1998. For additional information regarding
Year 2000 issues, see "Management's Discussion and Analysis of Financial
Condition and Results of Operations of the Company -- Certain Factors Affecting
Future Earnings of the Company and its Subsidiaries -- Impact of the Year 2000
Issue and Other System Implementation Issues" in Item 7 of the Form 10-K of
Reliant Energy, which has been jointly filed with the Resources Form 10-K.
NEW ACCOUNTING ISSUES
Reference is made to "Management's Discussion and Analysis of Financial
Condition and Results of Operations of the Company -- New Accounting Issues" in
Item 7 of the Form 10-K of Reliant Energy, which has been jointly filed with
the Resources Form 10-K, for discussion of certain new accounting issues.
112
<PAGE> 117
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA OF RESOURCES.
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
STATEMENTS OF CONSOLIDATED INCOME
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
---------------------------------- ----------------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTH TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, 1998 DECEMBER 31, 1997 JULY 31, 1997 DECEMBER 31, 1996
----------------- ----------------- ------------- -----------------
<S> <C> <C> <C> <C>
REVENUES...................................... $ 6,758,412 $ 2,526,182 $ 3,313,591 $ 4,788,462
----------- ----------- ----------- -----------
EXPENSES
Natural gas and purchased power, net .. 5,552,972 2,050,660 2,603,852 3,571,411
Operation and maintenance .............. 590,986 255,149 379,400 621,279
Depreciation and amortization .......... 191,891 78,087 84,901 142,362
Taxes other than income taxes .......... 112,258 50,386 73,142 116,600
Merger transaction costs ............... 1,144 17,256
Early retirement and severance ......... 22,344
----------- ----------- ----------- -----------
6,448,107 2,435,426 3,158,551 4,473,996
----------- ----------- ----------- -----------
Operating Income .......................... 310,305 90,756 155,040 314,466
----------- ----------- ----------- -----------
OTHER INCOME
Interest expense, net .................. (111,337) (47,490) (78,660) (132,557)
Dividend requirement on preferred
securities of subsidiary trust ....... (632) (279) (6,317) (5,842)
Loss on sale of accounts receivable .... (11,499)
Other, net ............................. 7,318 2,243 7,210 (3,078)
----------- ----------- ----------- -----------
(104,651) (45,526) (77,767) (152,976)
----------- ----------- ----------- -----------
Income Before Income Taxes ................ 205,654 45,230 77,273 161,490
Income Tax Expense ........................ 111,830 24,383 31,398 66,352
----------- ----------- ----------- -----------
Income Before Extraordinary Item .......... 93,824 20,847 45,875 95,138
Extraordinary gain (loss) on early
retirement of debt, less taxes ......... 237 (4,280)
----------- ----------- ----------- -----------
Net Income ................................ 93,824 20,847 46,112 90,858
Preferred dividend requirement ............ 3,597
----------- ----------- ----------- -----------
Earnings Available to Common Stock ........ $ 93,824 $ 20,847 $ 46,112 $ 87,261
=========== =========== =========== ===========
</TABLE>
See Notes to Resources' Consolidated Financial Statements
113
<PAGE> 118
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY AND COMPREHENSIVE INCOME
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
PREFERRED
COMMON STOCK (1) STOCK(2)
--------------------------------- ------------ PAID IN
SHARES AMOUNT AMOUNT CAPITAL
------------ ------------ ------------ ------------
<S> <C> <C> <C> <C>
FORMER RESOURCES:
Stockholders' Equity at December 31,
1995 ................................ 124,803,693 $ 78,002 $ 130,000 $ 880,885
Net Income ............................
Cash Dividend: ........................
Preferred stock - $1.50 per
share ............................
Common stock - $0.28 per share ......
Change in Market Value of
Marketable Equity Securities,
net tax $8,730 ......................
Conversion to Subordinated
Debentures .......................... (130,000)
Issuance of Common Stock under
Direct Stock Purchase Plan .......... 937,193 586 9,668
Public Issuance of Common Stock ....... 11,500,000 7,188 101,775
Other Issuances ....................... 667,287 417 8,725
Comprehensive Income ..................
------------ ------------ ------------ ------------
Stockholders' Equity at December 31,
1996 ................................ 137,908,173 86,193 1,001,053
------------ ------------ ------------ ------------
Net Income ............................
Cash Dividends: .......................
Common stock - $0.14 per share ......
Change in Market Value of
Marketable Equity Securities,
net tax of ($3,329) .................
Conversion of
Resources-Obligated
Mandatorily Redeemable
Convertible Preferred
Securities of Subsidiary Trust
Holding Solely Subordinated
Debentures of Resources to
Common Stock ........................ 11,428,262 7,143 131,425
Other Issuances ....................... 347,527 216 5,796
Comprehensive Income ..................
------------ ------------ ------------ ------------
Balance at July 31, 1997 .............. 149,683,962 93,552 1,138,274
------------ ------------ ------------ ------------
CURRENT RESOURCES (POST MERGER):
Adjustments due to Merger:
Eliminate Former Resources
Balances ............................ (149,683,962) (93,552) (1,138,274)
Capital contribution from Parent ...... 1,000 1 2,463,831
Net Income ............................
Change in Market Value of
Marketable Equity Securities,
net tax of $3,193 ...................
------------ ------------ ------------ ------------
Comprehensive Income ..................
Balance at December 31, 1997 .......... 1,000 1 2,463,831
------------ ------------ ------------ ------------
Net Income ............................
Change in Market Value of
Marketable Equity Securities,
net tax of $5,877 ...................
Comprehensive Income ..................
------------ ------------ ------------ ------------
Balance at December 31, 1998 .......... 1,000 $ 1 $ $ 2,463,831
============ ============ ============ ============
<CAPTION>
ACCUMULATED
OTHER TOTAL TOTAL
RETAINED COMPRE- STOCK- COMPRE-
EARNINGS HENSIVE HOLDER'S HENSIVE
(DEFICIT) INCOME EQUITY INCOME
--------- ------ ------ ------
<S> <C> <C> <C> <C>
FORMER RESOURCES:
Stockholders' Equity at December 31,
1995 ................................ $ (336,940) $ 15,316 $ 767,263
Net Income ............................ 90,858 90,858 $ 90,858
Cash Dividend: ........................
Preferred stock - $1.50 per
share ............................ (3,900) (3,900)
Common stock - $0.28 per share ...... (36,721) (36,721)
Change in Market Value of
Marketable Equity Securities,
net tax of 8,730 .................... (15,311) (15,311) (15,311)
Conversion to Subordinated
Debentures .......................... (130,000)
Issuance of Common Stock under
Direct Stock Purchase Plan .......... 10,254
Public Issuance of Common Stock ....... 108,963
Other Issuances ....................... 9,142
------------
Comprehensive Income .................. 75,547
------------ ------------ ------------ ------------
Stockholders' Equity at December 31,
1996 ................................ (286,703) 5 800,548
------------ ------------ ------------
Net Income ............................ 46,112 46,112 46,112
Cash Dividends: .......................
Common stock - $0.14 per share ...... (19,281) (19,281)
Change in Market Value of
Marketable Equity Securities,
net tax of (3,329) .................. 5,874 5,874 5,874
Conversion of
Resources-Obligated
Mandatorily Redeemable
Convertible Preferred
Securities of Subsidiary Trust
Holding Solely Subordinated
Debentures of Resources to
Common Stock ........................ 138,568
Other Issuances ....................... 6,012
------------
Comprehensive Income .................. 51,986
------------ ------------ ------------ ------------
Balance at July 31, 1997 .............. (259,872) 5,879 977,833
------------ ------------ ------------
CURRENT RESOURCES (POST MERGER):
Adjustments due to Merger:
Eliminate Former Resources
Balances ............................ 259,872 (5,879) (977,833)
Capital contribution from Parent ...... 2,463,832
Net Income ............................ 20,847 20,847 20,847
Change in Market Value of
Marketable Equity Securities,
net tax of 3,193 .................... (5,634) (5,634) (5,634)
------------
Comprehensive Income .................. 15,213
------------ ------------ ------------ ------------
Balance at December 31, 1997 .......... 20,847 (5,634) 2,479,045
------------ ------------ ------------
Net Income ............................ 93,824 93,824 93,824
Change in Market Value of
Marketable Equity Securities,
net tax of 5,877 .................... (10,370) (10,370) (10,370)
------------
Comprehensive Income .................. $ 83,454
------------ ------------ ------------ ------------
Balance at December 31, 1998 .......... $ 114,671 $ (16,004) $ 2,562,499
============ ============ ============
</TABLE>
- ---------
(1) $.625 par, authorized 250,000,000 shares. On the Acquisition Date,
Resources' pre-merger common stock was canceled and replaced with 1,000
shares of common stock (all of which are owned by Reliant Energy); see
Note 1(b).
(2) $3.00 Convertible exchangeable preferred stock, Series A ($50 liquidation
preference), cumulative, non-voting; authorized 10,000,000 shares, issued
and outstanding 2,600,000 shares. On the Acquisition Date, Resources'
pre-merger preferred stock was canceled.
See Notes to Resources' Consolidated Financial Statements
114
<PAGE> 119
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
ASSETS
DECEMBER 31, DECEMBER 31,
1998 1997
---------- ----------
<S> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents .............................. $ 26,576 $ 35,682
Accounts and notes receivable, principally customer .... 682,552 763,502
Unbilled revenue ....................................... 145,131 205,746
Accounts and notes receivable - affiliated companies ... 193,177 10,161
Gas in underground storage ............................. 79,855 63,702
Materials and supplies ................................. 33,947 29,611
Gas purchased in advance of delivery ................... 6,200 6,200
Fuel stock and petroleum products ...................... 81,230 345
Price risk management assets ........................... 265,203
Other current assets ................................... 33,034 55,092
---------- ----------
Total current assets ........................... 1,546,905 1,170,041
---------- ----------
PROPERTY, PLANT AND EQUIPMENT:
Natural gas ............................................ 1,686,159 1,488,961
Interstate pipelines.................................... 1,302,829 1,258,087
Other .................................................. 13,976 14,972
---------- ----------
Total .......................................... 3,002,964 2,762,020
Less accumulated depreciation and amortization ......... 187,936 59,531
---------- ----------
Property, plant and equipment -- net ................... 2,815,028 2,702,489
---------- ----------
OTHER ASSETS:
Goodwill, net .......................................... 2,050,386 2,026,395
Prepaid pension asset .................................. 102,021 92,064
Investment in marketable equity securities ............. 10,800 27,046
Regulatory asset for environmental costs ............... 20,695 21,745
Gas purchased in advance of delivery ................... 22,207 29,048
Deferred debits, net ................................... 87,479 93,010
---------- ----------
Total other assets ............................. 2,293,588 2,289,308
---------- ----------
TOTAL ASSETS ............................................. $6,655,521 $6,161,838
========== ==========
</TABLE>
See Notes to Resources' Consolidated Financial Statements
115
<PAGE> 120
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF DOLLARS) -- (CONTINUED)
LIABILITIES AND STOCKHOLDER'S EQUITY
<TABLE>
<CAPTION>
DECEMBER 31, DECEMBER 31,
1998 1997
----------- -----------
<S> <C> <C>
CURRENT LIABILITIES:
Current maturities of long-term debt ............................... $ 203,438 $ 232,145
Notes payable to banks ............................................. 390,000
Notes payable to parent ............................................ 22,100
Receivables facility ............................................... 300,000 300,000
Accounts payable, principally trade ................................ 622,262 668,269
Income taxes payable ............................................... 13,308
Interest payable ................................................... 36,197 27,273
Other taxes ........................................................ 42,107 41,315
Customer deposits .................................................. 36,985 36,626
Price risk management liabilities .................................. 227,652
Other current liabilities .......................................... 172,616 164,329
----------- -----------
Total current liabilities ...................................... 1,654,565 1,882,057
----------- -----------
DEFERRED CREDITS AND OTHER LIABILITIES:
Accumulated deferred income taxes .................................. 497,762 474,730
Estimated environmental remediation costs .......................... 20,695 21,745
Payable under capacity lease agreement ............................. 41,000 41,000
Benefit obligations ................................................ 158,762 182,687
Estimated obligations under indemnification provisions of sale
agreements ....................................................... 5,781 11,391
Refundable excess deferred income taxes ............................ 12,246 13,569
Other .............................................................. 187,765 117,621
----------- -----------
Total deferred credits and other liabilities ................... 924,011 862,743
----------- -----------
RESOURCES-OBLIGATED MANDATORILY REDEEMABLE CONVERTIBLE PREFERRED
SECURITIES OF SUBSIDIARY TRUST HOLDING SOLELY JUNIOR SUBORDINATED
DEBENTURES OF RESOURCES, NET ....................................... 1,157 21,290
LONG-TERM DEBT, LESS CURRENT MATURITIES ............................... 1,513,289 916,703
STOCKHOLDER'S EQUITY:
Common stock ....................................................... 1 1
Paid-in capital .................................................... 2,463,831 2,463,831
Retained earnings .................................................. 114,671 20,847
Accumulated other comprehensive income ............................. (16,004) (5,634)
----------- -----------
Total stockholder's equity ..................................... 2,562,499 2,479,045
----------- -----------
COMMITMENTS AND CONTINGENCIES (NOTE 8)
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY ......................... $ 6,655,521 $ 6,161,838
=========== ===========
</TABLE>
See Notes to Resources' Consolidated Financial Statements
116
<PAGE> 121
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
STATEMENTS OF CONSOLIDATED CASH FLOWS
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
-------------------------------------- ------------------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, 1998 DECEMBER 31, 1997 JULY 31, 1997 DECEMBER 31, 1996
----------------- ----------------- -------------- -----------------
<S> <C> <C> <C> <C>
Cash Flows from Operating Activities:
Net income ............................... $ 93,824 $ 20,847 $ 46,112 $ 90,858
Adjustments to reconcile net income
to net cash provided by (used in)
operating activities:
Depreciation and amortization .......... 191,891 78,087 84,901 142,362
Deferred income taxes .................. 31,810 36,770 14,589 28,809
Early retirement and severance,
less cash cost ...................... 12,941
Extraordinary (gain) loss, less taxes... (237) 4,280
Utilization of tax loss
carryforwards ....................... (2,405)
Changes in other assets and
liabilities, net of the effects
of the acquisition:
Accounts and notes receivable-net .... (41,451) (361,285) 313,586 (353,703)
Inventories .......................... (102,125) (2,250) 9,980 (14,895)
Deferred gas costs ................... (9,297) 8,655 (7,715) 12,788
Other current assets ................. 18,719 (1,298) (1,128) 10,935
Accounts payable ..................... (67,024) 148,071 (224,590) 266,446
Interest and taxes accrued ........... 13,454 (13,402) (19,996) 4,712
Other current liabilities ............ 9,416 42,284 (22,633) 10,483
Net price risk management
activities ........................ (29,857)
Recoveries under gas contract
disputes .......................... 6,841 2,600 5,500 10,900
Other-net ............................ (10,942) 10,677 903 3,642
----------- ----------- ----------- -----------
Net cash provided by (used in)
operating activities ............. 105,259 (30,244) 199,272 228,153
----------- ----------- ----------- -----------
Cash Flows from Investing Activities:
Purchase of Former Resources, net of
cash acquired .......................... (1,422,672)
Capital expenditures ..................... (253,972) (93,414) (88,638) (172,200)
Other, net ............................... 8,068 (1,079) (6,424) (4,957)
----------- ----------- ----------- -----------
Net cash used in investing
activities........................ $ (245,904) $(1,517,165) $ (95,062) $ (177,157)
=========== =========== =========== ===========
(continued on next page)
</TABLE>
117
<PAGE> 122
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
STATEMENTS OF CONSOLIDATED CASH FLOWS
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
(THOUSANDS OF DOLLARS)
(CONTINUED)
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
------------------------------------- ----------------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, 1998 DECEMBER 31, 1997 JULY 31, 1997 DECEMBER 31, 1996
----------------- ----------------- ------------- -----------------
<S> <C> <C> <C> <C>
Cash Flows from Financing Activities:
Cash portion of capital contribution
from Reliant Energy ................. $ 1,426,067
Retirements and reacquisitions of
long-term debt ........................ $ (226,604) (165,808) $ (230,667) $ (396,733)
Proceeds from bank term loan ............ 150,000
Public issuance of common stock ......... 108,963
Public issuance of convertible ..........
preferred securities by subsidiary ....
trust ................................. 167,756
Other debt borrowings (repayments) ...... (424,299) 317,500 (42,500) 105,000
Proceeds from issuance of debentures .... 812,849
Increase in receivables facility ........ 24,000 41,000
Issuance of common stock under
direct stock purchase plan, net ....... 10,254
Common and preferred stock dividends .... (19,281) (40,621)
Redemption of convertible securities .... (10,450) (9,504)
Increase (decrease) in overdrafts ....... (19,957) (9,164) (27,348) 9,055
----------- ----------- ----------- -----------
Net cash provided by (used in)
financing activities ............. 131,539 1,583,091 (128,796) (36,326)
----------- ----------- ----------- -----------
Net Increase (Decrease) in Cash and
Cash Equivalents ...................... (9,106) 35,682 (24,586) 14,670
Cash and Cash Equivalents at Beginning
of the Period ......................... 35,682 27,981 13,311
----------- ----------- ----------- -----------
Cash and Cash Equivalents at End of the ...
Period ................................ $ 26,576 $ 35,682 $ 3,395 $ 27,981
=========== =========== =========== ===========
Supplemental Disclosure of Cash Flow
Information:
Cash Payments:
Interest (net of amounts capitalized) ... $ 105,393 $ 55,951 $ 67,100 $ 140,751
Income taxes, net ....................... 46,522 714 20,900 29,657
</TABLE>
The aggregate consideration paid to stockholders of Former Resources
in connection with the Merger consisted of $1.4 billion in cash and 47.8
million shares of Reliant Energy common stock valued at approximately $1.0
billion. The overall transaction was valued at $4.0 billion consisting of $2.4
billion for Former Resources' common stock and common stock equivalents and
$1.6 billion of Former Resources debt. A significant portion ($139 million) of
the securities of a subsidiary trust was converted to Common Stock of Resources
in non-cash transactions prior to the Merger; see Note 5.
See Notes to Resources' Consolidated Financial Statements
118
<PAGE> 123
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
FOR THE THREE YEARS ENDED DECEMBER 31, 1998
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) Nature of Operations.
Reliant Energy Resources Corp. (formerly NorAm Energy Corp.) (Resources),
a Delaware corporation, is a wholly owned subsidiary of Houston Industries
Incorporated d/b/a Reliant Energy, Incorporated (Reliant Energy). Resources is
principally engaged in the natural gas industry, including gathering,
transmission, marketing, storage and distribution. Collectively, these
operations accounted for greater than 95% of Resources' total revenues, income
or loss and identifiable assets during 1998.
Resources' natural gas distribution operations (Natural Gas Distribution)
are conducted by three of its unincorporated divisions: Reliant Energy Entex,
Reliant Energy Minnegasco and Reliant Energy Arkla. Resources' interstate
pipeline operations (Interstate Pipelines) are conducted by its wholly owned
subsidiaries, Reliant Energy Gas Transmission Company (REGT) and Mississippi
River Transmission Corporation (MRT). Resources' wholesale energy marketing
activities are conducted primarily by Reliant Energy Services, Inc. (Reliant
Energy Services) and its gathering activities are conducted by Reliant Energy
Field Services, Inc. (Reliant Energy Field Services). Resources' retail
marketing activities are conducted by Reliant Energy Retail, Inc. (Reliant
Energy Retail). Resources' principal operations are located in Arkansas,
Louisiana, Minnesota, Mississippi, Missouri, Oklahoma and Texas.
In February 1999, NorAm Energy Corp. changed its name to Reliant Energy
Resources Corp. and Houston Industries Incorporated began doing business as
Reliant Energy, Incorporated.
For information regarding Resources' reportable segments, see Note 9.
(b) Merger with Reliant Energy, Incorporated.
On August 6, 1997 (Acquisition Date), the former parent corporation
(Former HII) of Reliant Energy merged with and into Reliant Energy, and NorAm
Energy Corp. (Former Resources) merged with and into Resources. Effective upon
the mergers (collectively, the Merger), each outstanding share of common stock
of Former HII was converted into one share of common stock (including
associated preference stock purchase rights) of Reliant Energy, and each
outstanding share of common stock of Former Resources was converted into the
right to receive $16.3051 cash or 0.74963 shares of common stock of Reliant
Energy. The aggregate consideration paid to Former Resources stockholders in
connection with the Merger consisted of $1.4 billion in cash and 47.8 million
shares of Reliant Energy's common stock valued at approximately $1.0 billion.
The overall transaction was valued at $4.0 billion consisting of $2.4 billion
for Former Resources' common stock and common stock equivalents and $1.6
billion of Former Resources' debt ($1.3 billion of which was long-term debt).
The Merger was recorded under the purchase method of accounting with
assets and liabilities of Resources reflected at their estimated fair values as
of the Acquisition Date, resulting in a "new basis" of accounting. In
Resources' consolidated financial statements (Resources' Consolidated Financial
Statements), periods which reflect the new basis of accounting are labeled as
"Current Resources" and periods which do not reflect the new basis of
accounting are labeled "Former Resources". Former Resources' Statement of
Consolidated Income for the seven months ended July 31, 1997 included certain
adjustments from August 1, 1997 to the Acquisition Date for pre-merger
transactions.
119
<PAGE> 124
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Resources' Consolidated Balance Sheets for periods after the Acquisition
Date reflect adjustments associated with Reliant Energy's allocation of the
purchase price, principally consisting of (i) the revaluation of certain
property, plant and equipment and long-term debt to their estimated fair market
value, (ii) the recognition of certain pension and postretirement benefit
obligations previously being recognized through amortization, (iii) the
recognition of goodwill as described above, (iv) the elimination of Resources'
historical goodwill, (v) the elimination of Resources' historical stockholders'
equity balances and accumulated depreciation and amortization as of the
Acquisition Date and (vi) the recognition of the associated deferred income tax
effects. In addition, Resources' pre-merger common stock was canceled and
replaced with 1,000 shares of common stock (all of which are owned by Reliant
Energy), rendering presentation of per share data no longer meaningful. Reliant
Energy's debt to fund the cash portion of the purchase consideration has not
been allocated or "pushed down" to Resources and is not reflected on Resources'
Consolidated Financial Statements.
Resources' Statements of Consolidated Income for periods after the
Acquisition Date are principally affected by (i) the amortization (over 40
years) of the newly-recognized goodwill, partially offset by the elimination of
the amortization of Resources' historical goodwill, (ii) the amortization (to
interest expense) of the revaluation of long-term debt, (iii) the removal of
the amortization (to operating expense) previously associated with the pension
and postretirement obligations as described above and (iv) the deferred income
tax expense associated with these adjustments. Interest expense on Reliant
Energy's debt which was used to fund the cash portion of the acquisition has
not been allocated or "pushed down" to Resources and is not reflected on
Resources' Consolidated Financial Statements. For these reasons, among others,
certain financial information for periods before and after the Acquisition Date
is not comparable.
If the Merger had occurred on January 1, 1997 and 1996, Resources'
unaudited pro forma net income for 1997 and 1996 would have been $66 million
and $83 million, respectively. Pro forma results, which are based on
assumptions deemed appropriate by Resources' management, have been prepared for
informational purposes only and are not necessarily indicative of the results
which would have resulted had the Merger actually taken place on the date
indicated.
(c) Regulatory Assets and Regulation.
In general, Resources' Interstate Pipelines operations are subject to
regulation by the Federal Energy Regulatory Commission, while its Natural Gas
Distribution operations are subject to regulation at the state or municipal
level. Historically, all of Resources' rate-regulated businesses have followed
the accounting guidance contained in Statement of Financial Accounting Standards
No. 71, "Accounting for the Effects of Certain Types of Regulation" (SFAS No.
71). Resources discontinued application of SFAS No. 71 to REGT in 1992. As a
result of the continued application of SFAS No. 71 to MRT and the Natural Gas
Distribution operations, Resources' financial statements contain assets and
liabilities which would not be recognized by unregulated entities.
At December 31, 1998 Resources' Consolidated Balance Sheet included
approximately $12 million in regulatory assets recorded as deferred debits.
These assets represent probable future revenue to Resources associated with
certain incurred costs as these costs are recovered through the rate making
process. These costs are being recovered through rates over varying periods up
to 40 years.
(d) Principles of Consolidation.
Resources' Consolidated Financial Statements include the accounts of
Resources and its wholly owned subsidiaries. All significant intercompany
transactions and balances are eliminated in consolidation.
120
<PAGE> 125
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(e) Property, Plant and Equipment.
Property, plant and equipment has been revalued to estimated fair market
value as of the Acquisition Date in accordance with the purchase method of
accounting, and depreciated or amortized on a straight-line basis over their
estimated useful lives (for additional information regarding the accounting of
the Merger, see Note 1(b) above). Prior to the Acquisition Date, such assets
were carried at cost. Additions to and betterments of utility property are
charged to property accounts at cost, while the costs of maintenance, repairs
and minor replacements are charged to expense as incurred. Upon normal
retirement of units of utility property, plant and equipment, the cost of such
property, together with cost of removal less salvage, is charged to accumulated
depreciation.
(f) Depreciation and Amortization Expense.
Goodwill, none of which is being recovered in regulated service rates, is
amortized on a straight-line basis over 40 years. Approximately $53.6 million
of goodwill was amortized during 1998. Approximately $29.9 million of goodwill
was amortized during 1997 of which $21.6 million represents amortization
related to the Merger and was incurred during the period from the Acquisition
Date through December 31, 1997. Goodwill amortization for 1996 was
approximately $14.2 million. Resources regularly compares the carrying value of
its goodwill to the anticipated undiscounted future operating income from the
businesses whose acquisition gave rise to the goodwill and no impairment is
indicated or expected. For additional information regarding the amortization of
goodwill in connection with the Merger, see Note 1(b) above.
(g) Gas in Underground Storage.
Inventories principally follow the average cost method. Gas inventory (at
average cost) was $79.9 million and $63.7 million at December 31, 1998 and
1997, respectively. All non-utility inventories held for resale are valued at
the lower of cost or market.
(h) Fuel Stock and Petroleum Products.
Fuel stock and petroleum products, principally heating oil, are used in
trading operations and are marked-to-market in connection with the price risk
management activities discussed in Note 2.
(i) Revenues.
Resources' rate-regulated divisions/subsidiaries bill customers on a
monthly cycle billing basis. Revenues are recorded on an accrual basis,
including an estimate for gas delivered but unbilled at the end of each
accounting period.
(j) Statements of Consolidated Cash Flows.
For purposes of reporting cash flows, cash equivalents are considered to
be short-term, highly liquid investments readily convertible into cash.
(k) Derivative Financial Instruments (Risk Management).
For information regarding Resources' accounting for derivative financial
instruments associated with natural gas, electric power and transportation risk
management activities, see Note 2.
For information regarding a change in accounting principle for trading
activities see Note 1 (r).
(l) Income Taxes.
Reliant Energy files a consolidated federal income tax return in which
Resources and its subsidiaries are included (as of the Acquisition Date).
Reliant Energy follows a policy of comprehensive interperiod income tax
allocation. For additional information regarding income taxes, see Note 7.
121
<PAGE> 126
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(m) Investments in Marketable Equity Securities.
A subsidiary of Resources holds certain equity securities classified as
"available-for-sale" and reports such investments at estimated fair value with
any unrealized gain or loss, net of tax, as a component of accumulated other
comprehensive income. At December 31, 1998 and 1997, Resources' unrealized loss
relating to these marketable equity securities was approximately $16 million
and $5.6 million, respectively, net of tax.
(n) Early Retirement and Severance.
Prior to the Merger, during the first quarter of 1996, Resources
instituted several early retirement and reorganization plans, pursuant to which
a total of approximately 400 positions were eliminated resulting in expense for
severance payments and enhanced retirement benefits reported as a non-recurring
pre-tax charge of approximately $22.3 million (approximately $13.4 million
after tax).
(o) Merger Transaction Costs.
"Merger transaction costs" include expenses associated with completion of
the business combination with Reliant Energy (see Note 1(b)), principally
consisting of investment banking and legal fees.
(p) Allowance for Doubtful Accounts.
Accounts and notes receivable, principally customer, as presented on
Resources' Consolidated Balance Sheets are net of an allowance for doubtful
accounts of $14.4 million and $15.3 million at December 31, 1998 and 1997,
respectively.
(q) Related Party Transactions.
Reliant Energy has established a "money fund" through which Resources can
borrow or invest on a short-term basis. Investments of Resources, reflected
within accounts and notes receivable-affiliated companies, totaled $181 million
at December 31, 1998. Borrowings of Resources, reflected within notes payable
to parent, totaled $22 million at December 31, 1997. Interest expense on such
borrowings was $0.2 million for the year ended December 31, 1998. Interest
income on such investments was $5.1 million for the year ended December 31,
1998.
Certain subsidiaries of Resources have entered into office rental
agreements with Reliant Energy. In 1998, subsidiaries of Resources paid $0.9
million of rent expense to Reliant Energy.
122
<PAGE> 127
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(r) Change in Accounting Principle
In the fourth quarter of 1998, Resources adopted mark-to-market accounting
for all of the energy price risk management and trading activities of Reliant
Energy Services. Under mark-to-market accounting, Resources records the fair
value of energy-related derivative financial instruments, including physical
forward contracts, swaps, options and exchange-traded futures contracts, at each
balance sheet date. Such amounts are recorded in Resources' Consolidated Balance
Sheet as price risk management assets, price risk management liabilities,
deferred debits and deferred liabilities. The realized and unrealized gains
(losses) are recorded as a component of operating revenues in Resources'
Consolidated Statements of Income. Resources has applied mark-to-market
accounting retroactively to January 1, 1998. This change was made in order to
adopt a generally accepted accounting methodology that provided consistency
between financial reporting and the methodology used in all reported periods by
Resources in managing its trading activities. There was no material cumulative
effect resulting from the accounting change.
Resources will adopt Emerging Issues Task Force Issue 98-10, "Accounting
for Contracts Involved in Energy Trading and Risk Management Activities" in the
first quarter of 1999 for Reliant Energy Services' trading activities. Resources
does not expect the implementation of EITF Issue 98-10 to be material to its
consolidated financial statements.
(s) Reclassifications and Use of Estimates.
Certain amounts from the previous years have been reclassified to conform
to the 1998 presentation of financial statements. Such reclassifications do not
affect earnings.
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates.
(t) New Accounting Pronouncement.
In 2000, Resources expects to adopt Statement of Financial Accounting
Standards No. 133, "Accounting for Derivative Instruments and Hedging
Activities" (SFAS No. 133), which establishes accounting and reporting
standards for derivative instruments, including certain derivative instruments
embedded in other contracts and for hedging activities. Resources is in the
process of determining the effect of adoption of SFAS No. 133.
(2) DERIVATIVE FINANCIAL INSTRUMENTS
(a) Price Risk Management and Trading Activities.
Resources, through its subsidiary, Reliant Energy Services, offers energy
price risk management services primarily in the natural gas, electric and crude
oil and refined product industries. Reliant Energy Services provides these
services by utilizing a variety of derivative financial instruments, including
fixed and variable-priced physical forward contracts, fixed-price swap
agreements, variable-price swap agreements, exchange-traded energy futures and
option contracts, and swaps and options traded in the over-the-counter financial
markets (Trading Derivatives). Fixed-price swap agreements require payments to,
or receipts of payments from, counterparties based on the differential between a
fixed and variable price for the commodity. Variable-price swap agreements
require payments to, or receipts of payments from, counterparties based on the
differential between industry pricing publications or exchange quotations.
Prior to 1998 Reliant Energy Services applied hedge accounting to certain
physical commodity activities that qualified for hedge accounting. In 1998,
Reliant Energy Services adopted mark-to-market accounting for all of its price
risk management and trading activities. Accordingly, as of such date, such
Trading Derivatives are recorded at fair value with realized and unrealized
gains (losses) recorded as a component of operating revenues in Resources'
Consolidated Statements of Income. The recognized, unrealized balance is
recorded as price risk management assets/liabilities and deferred debits/credits
on Resources' Consolidated Balance Sheets (See Note 1(r)).
The notional quantities, maximum terms and the estimated fair value of
Trading Derivatives at December 31, 1998 are presented below (volumes in
billions of British thermal units equivalent (BBtue) and dollars in millions):
<TABLE>
<CAPTION>
VOLUME-FIXED
VOLUME-FIXED PRICE MAXIMUM
1998 PRICE PAYOR RECEIVER TERM (YEARS)
---- ----------- -------- ------------
<S> <C> <C> <C>
Natural gas.................................................. 937,264 977,293 9
Electricity.................................................. 122,950 124,878 3
Crude oil and products....................................... 205,499 204,223 3
</TABLE>
123
<PAGE> 128
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
AVERAGE FAIR
FAIR VALUE VALUE (a)
--------------------------- ---------------------------
1998 ASSETS LIABILITIES ASSETS LIABILITIES
---- ------ ----------- ------ -----------
<S> <C> <C> <C> <C>
Natural gas.............................................. $ 224 $ 213 $ 124 $ 108
Electricity.............................................. 34 33 186 186
Crude oil and products................................... 29 23 21 17
--------- --------- --------- ---------
$ 287 $ 269 $ 331 $ 311
</TABLE>
The notional quantities, maximum terms and the estimated fair value of
derivative financial instruments at December 31, 1997 are presented below
(volumes in BBtue and dollars in millions):
<TABLE>
<CAPTION>
VOLUME-FIXED
VOLUME-FIXED PRICE MAXIMUM
1997 PRICE PAYOR RECEIVER TERM (YEARS)
----
<S> <C> <C> <C>
Natural gas.................................................. 85,701 64,890 4
Electricity.................................................. 40,511 42,976 1
</TABLE>
<TABLE>
<CAPTION>
AVERAGE FAIR
FAIR VALUE VALUE (A)
--------------------------- ---------------------------
1997 ASSETS LIABILITIES ASSETS LIABILITIES
---- ------ ----------- ------ -----------
<S> <C> <C> <C> <C>
Natural gas.............................................. $ 46 $ 39 $ 56 $ 48
Electricity.............................................. 6 6 3 2
------- ------- ------- -------
$ 52 $ 45 $ 59 $ 50
</TABLE>
- ---------
(a) Computed using the ending balance of each month.
In addition to the fixed-price notional volumes above, Reliant Energy
Services also has variable-priced agreements, as discussed above, totaling
1,702,977 and 101,465 BBtue as of December 31, 1998 and 1997, respectively.
Notional amounts reflect the volume of transactions but do not represent the
amounts exchanged by the parties to the financial instruments. Accordingly,
notional amounts do not accurately measure Resources' exposure to market or
credit risks.
All of the fair values shown in the table above at December 31, 1998 and
substantially all at December 31, 1997 have been recognized in income. The fair
value as of December 31, 1998 and 1997 was estimated using quoted prices where
available and considering the liquidity of the market for the Trading
Derivatives. The prices are subject to significant changes based on changing
market conditions.
At December 31, 1998, $22 million of the fair value of the assets and $41
million of the fair value of the liabilities are recorded as long-term in
deferred debits and deferred credits, respectively, on Resources' Consolidated
Balance Sheets.
The weighted-average term of the trading portfolio, based on volumes, is
less than one year. The maximum and average terms disclosed herein are not
indicative of likely future cash flows, as these positions may be changed by
new transactions in the trading portfolio at any time in response to changing
market conditions, market liquidity and Resources' risk management portfolio
needs and strategies. Terms regarding cash settlements of these contracts vary
with respect to the actual timing of cash receipts and payments.
In addition to the risk associated with price movements, credit risk is
also inherent in Resources', and its subsidiaries' risk management activities.
Credit risk relates to the risk of loss resulting from non-performance of
contractual obligations by a counterparty. The following table shows the
composition of the total price risk management assets of Reliant Energy
Services as of December 31, 1998.
124
<PAGE> 129
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
INVESTMENT
GRADE (1) TOTAL
----------------- -----------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
Energy marketers.......................................................... $ 102,458 $ 123,779
Financial institutions.................................................... 61,572 61,572
Gas and electric utilities................................................ 46,880 48,015
Oil and gas producers..................................................... 7,197 8,323
Industrials............................................................... 1,807 3,233
Independent power producers............................................... 1,452 1,463
Others.................................................................... 45,421 46,696
------------- -------------
Total................................................................ $ 266,787 293,081
=============
Credit and other reserves................................................. (6,464)
-------------
Energy price risk management assets(2).................................... $ 286,617
=============
</TABLE>
- ---------
(1) "Investment Grade" is primarily determined using publicly available credit
ratings along with the consideration of credit support (e.g., parent
company guarantees) and collateral, which encompass cash and standby
letters of credit.
(2) Resources has credit risk exposure with respect to two investment grade
customers, each of which represents an amount greater than 5% but less than
10% of Price Risk Management Assets.
(b) Non-Trading Activities.
To reduce the risk from market fluctuations in the price of electric
power, natural gas and related transportation, Resources and certain of its
subsidiaries enter into futures transactions, swaps and options (Energy
Derivatives) in order to hedge certain natural gas in storage, as well as
certain expected purchases, sales and transportation of natural gas and
electric power (a portion of which are firm commitments at the inception of the
hedge). Energy Derivatives are also utilized to fix the price of compressor
fuel or other future operational gas requirements, although usage to date for
this purpose has not been material. Resources applies hedge accounting with
respect to its derivative financial instruments.
Certain subsidiaries of Resources also utilize interest rate derivatives
(principally interest rate swaps) in order to adjust the portion of its overall
borrowings which are subject to interest rate risk and also utilize such
derivatives to effectively fix the interest rate on debt expected to be issued
for refunding purposes.
For transactions involving either Energy Derivatives or interest rate
derivatives, hedge accounting is applied only if the derivative (i) reduces the
price risk of the underlying hedged item and (ii) is designated as a hedge at
its inception. Additionally, the derivatives must be expected to result in
financial impacts which are inversely correlated to those of the item(s) to be
hedged. This correlation (a measure of hedge effectiveness) is measured both at
the inception of the hedge and on an ongoing basis, with an acceptable level of
correlation of at least 80% for hedge designation. If and when correlation
ceases to exist at an acceptable level, hedge accounting ceases and
mark-to-market accounting is applied.
In the case of interest rate swaps associated with existing obligations,
cash flows and expenses associated with the interest rate derivative
transactions are matched with the cash flows and interest expense of the
obligation being hedged, resulting in an adjustment to the effective interest
rate. When interest rate swaps are utilized to effectively fix the interest
rate for an anticipated debt issuance, changes in the market value of the
interest rate derivatives are deferred and recognized as an adjustment to the
effective interest rate on the newly issued debt.
Unrealized changes in the market value of Energy Derivatives utilized as
hedges are not generally recognized in Resources' Consolidated Statements of
Income until the underlying hedged transaction occurs. Once it becomes
125
<PAGE> 130
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
probable that an anticipated transaction will not occur, deferred gains and
losses are recognized. In general, the financial impact of transactions
involving these Energy Derivatives is included in Resources' Statements of
Consolidated Income under the captions (i) fuel expenses, in the case of
natural gas transactions and (ii) purchased power, in the case of electric
power transactions. Cash flows resulting from these transactions in Energy
Derivatives are included in Resources' Statements of Consolidated Cash Flows in
the same category as the item being hedged.
At December 31, 1998, subsidiaries of Resources were fixed-price payors
and fixed-price receivers in Energy Derivatives covering 42,498 billion British
thermal units (BBtu) and 3,930 BBtu of natural gas, respectively. At December
31, 1997, subsidiaries of Resources were fixed-price payors and fixed-price
receivers in Energy Derivatives covering 38,754 BBtu and 7,647 BBtu of natural
gas, respectively. Also, at December 31, 1998 and 1997, subsidiaries of
Resources were parties to variable-priced Energy Derivatives totaling 21,437
BBtu and 3,630 BBtu of natural gas, respectively. The weighted average maturity
of these instruments is less than one year.
The notional amount is intended to be indicative of Resources' and its
subsidiaries' 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 Energy
Derivatives 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, as further discussed below. Under such circumstances, gains
(losses) are deferred and recognized as a component of income when the
underlying hedged item is recognized in income.
The average maturity discussed above and the fair value discussed in Note
10 are not necessarily indicative of likely future cash flows as these
positions may be changed by new transactions in the trading portfolio at any
time in response to changing market conditions, market liquidity and Resources'
risk management portfolio needs and strategies. Terms regarding cash
settlements of these contracts vary with respect to the actual timing of cash
receipts and payments.
(c) Trading and Non-trading -- General Policy.
In addition to the risk associated with price movements, credit risk is
also inherent in Resources' and its subsidiaries' risk management activities.
Credit risk relates to the risk of loss resulting from non-performance of
contractual obligations by a counterparty. While as yet Resources and its
subsidiaries have experienced only minor losses due to the credit risk
associated with these arrangements, Resources has off-balance sheet risk to the
extent that the counterparties to these transactions may fail to perform as
required by the terms of each such contract. In order to minimize this risk,
Resources and/or its subsidiaries, as the case may be, enter into such
contracts primarily with those counterparties with a minimum Standard & Poor's
or Moody's rating of BBB- or Baa3, respectively. For long-term arrangements,
Resources and its subsidiaries periodically review the financial condition of
such firms in addition to monitoring the effectiveness of these financial
contracts in achieving Resources' objectives. Should the counterparties to
these arrangements fail to perform, Resources would seek to compel performance
at law or otherwise or obtain compensatory damages in lieu thereof. Resources
might be forced to acquire alternative hedging arrangements or be required to
honor the underlying commitment at then-current market prices. In such event,
Resources might incur additional loss to the extent of amounts, if any, already
paid to the counterparties. In view of its criteria for selecting
counterparties, its process for monitoring the financial strength of these
counterparties and its experience to date in successfully completing these
transactions, Resources believes that the risk of incurring a significant
financial statement loss due to the non-performance of counterparties to these
transactions is minimal.
Resources' policies prohibit the use of leveraged financial instruments.
126
<PAGE> 131
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(3) CAPITAL STOCK
(a) Earnings Per Share.
As a result of the Merger, Resources is no longer required to present
earnings per share (EPS) data as its common shares (all of which are owned by
Reliant Energy) are not publicly held. EPS data for 1998, 1997 and 1996 has not
been included because Resources believes it is no longer meaningful.
(b) Direct Stock Purchase Plan and Dividend Reinvestment Plan.
Resources' Direct Stock Purchase Plan and Dividend Reinvestment Plan were
suspended and canceled in connection with the Merger.
(4) LONG-TERM AND SHORT-TERM FINANCING
(a) Short-term Financing.
In 1998, Resources met its short-term financing needs primarily through a
bank facility, bank lines of credit, a receivables facility and the issuance of
commercial paper. In March 1998, Resources replaced its $400 million revolving
credit facility with a five-year $350 million revolving credit facility
(Resources Credit Facility). Borrowings under the Resources Credit Facility are
unsecured and bear interest at a rate based upon either the London interbank
offered rate (LIBOR) plus a margin, a base rate or a rate determined through a
bidding process. The Resources Credit Facility is used to support Resources'
issuance of up to $350 million of commercial paper. There were no commercial
paper borrowings and no loans outstanding under the Resources Credit Facility
at December 31, 1998. Borrowings under Resources' prior credit facility at
December 31, 1997 were $340 million. In addition, Resources had $50 million of
outstanding loans under uncommitted lines of credit at December 31, 1997 having
a weighted average interest rate of 6.82%.
A $65 million committed bank facility under which Resources obtained
letters of credit and all of Resources' uncommitted lines of credit were
terminated in 1998. Subsequent to the December 1998 termination, Resources
obtained letters of credit under an uncommitted line. Resources expects to amend
the Resources Credit Facility in March 1999 to add a $65 million letter of
credit subfacility.
Under a trade receivables facility (Receivables Facility) which expires in
August 1999, Resources sells, with limited recourse, an undivided interest
(limited to a maximum of $300 million) in a designated pool of accounts
receivable. The amount of receivables sold and uncollected was $300 million at
December 31, 1998 and at December 31, 1997. The weighted average interest rate
was approximately 5.54% at December 31, 1998 and 5.65% at December 31, 1997.
Certain of Resources' remaining receivables serve as collateral for receivables
sold and represent the maximum exposure to Resources should all receivables sold
prove ultimately uncollectible. Resources has retained servicing responsibility
under the Receivables Facility for which it is paid a servicing fee. Pursuant to
SFAS No. 125, "Accounting for Transfers and Servicing of Financial Assets and
Extinguishment of Liabilities", Resources accounts for amounts transferred
pursuant to the Receivables Facility as collateralized borrowings. As a result,
these receivables are recorded as assets on Resources' Consolidated Balance
Sheet and amounts received by Resources pursuant to this facility are recorded
as a current liability under the caption "Receivables Facility."
(b) Long-term Debt.
Resources' consolidated long-term debt outstanding, which is summarized in
the following table, is noncallable and without sinking fund requirements
except as noted. Carrying amounts and amounts due in one year reflect $33.2
million and $3.4 million, respectively, for fair value adjustments recorded in
connection with the Merger.
127
<PAGE> 132
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
DECEMBER 31, 1998
--------------------------------------------------------
CARRYING AMOUNTS
----------------------------
EFFECTIVE PRINCIPAL NON-CURRENT CURRENT
RATE AMOUNT PORTION PORTION
---- ------ ------- -------
(MILLIONS OF DOLLARS)
<S> <C> <C> <C> <C>
Medium-term notes, Series A and B due through
2001, weighted average rate of 8.96% at
December 31, 1998................................... 6.4% $ 165.6 $ 177.6
8.875% Series due 1999................................. 6.3% 200.0 $ 202.7
7.5% Series due 2000................................... 6.4% 200.0 203.1
8.9% Series due 2006................................... 6.8% 145.1 163.4
6% Convertible Subordinated Debentures due 2012........ 6.5% 109.6 104.6
10% Series due 2019(1)................................. 8.8% 42.8 47.6
6 1/2% Series due 2008................................. 6.5% 300.0 300.0
6 %% Series due 2003................................... 6.4% 517.0 517.0
Other.................................................. 0.7
---------- ---------- ----------
$ 1,680.1 $ 1,513.3 $ 203.4
========== ========== ==========
<CAPTION>
DECEMBER 31, 1997
--------------------------------------------------------
CARRYING AMOUNTS
----------------------------
EFFECTIVE PRINCIPAL NON-CURRENT CURRENT
RATE AMOUNT PORTION PORTION
---- ------ ------- -------
(MILLIONS OF DOLLARS)
<S> <C> <C> <C> <C>
Medium-term notes, Series A and B due through
2001, weighted average rate of 8.90% at
December 31, 1997............................ 6.4% $ 241.6 $ 183.8 $ 78.8
Bank Term Loan due 1998................................ 6.2% 150.0 153.3
8.875% Series due 1999................................. 6.3% 200.0 207.2
7.5% Series due 2000................................... 6.4% 200.0 205.0
8.9% Series due 2006................................... 6.8% 145.1 165.1
6% Convertible Subordinated Debentures due 2012........ 6.5% 116.3 107.2
10% Series due 2019(1)................................. 8.8% 42.8 47.8
Other.................................................. 4.1% 0.6 0.6
---------- ---------- -----------
$ 1,096.4 $ 916.7 $ 232.1
========== ========== ===========
</TABLE>
- ----------
(1) In the fourth quarter of 1997 Resources purchased $101.4 million aggregate
principal amount of its 10% Debentures due 2019 at an average price of
111.98% plus accrued interest. Because Resources' debt was stated at fair
market value as of the Acquisition Date, the loss on the reacquisition of
these debentures was not material.
Consolidated maturities of long-term debt and sinking fund requirements
for Resources are approximately $207 million for 1999, $228 million in 2000,
$151 million in 2001, $7 million in 2002 and $7 million in 2003.
Resources' retirements and reacquisitions of long-term debt are summarized
in the following table. In cases where premiums were paid or discounts were
realized in association with these reacquisitions and retirements, such amounts
are reported in Resources' Statements of Consolidated Income as "Extraordinary
gain (loss) on early retirement of debt, less taxes" and are net of taxes of
$0.1 million and ($2.5) million in 1997 and 1996, respectively. For retirements
and reacquisitions after the Acquisition Date, gains or losses on early
retirement are immaterial since the carrying amounts reflect the fair value
adjustments described above.
128
<PAGE> 133
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------
1998(1) 1997(1)
------- -------
<S> <C> <C>
Reacquisition of 10% Debentures due 2019................................. $ 101.4
Reacquisition of 6% Convertible Subordinated Debentures due 2012(2)...... $ 6.7 5.8
Retirement, at maturity, of Medium Term Notes(3)......................... 76.0 52.0
Retirement of Bank Term Loan due 2000.................................... 150.0
Retirement of 9.875% Notes due 1997...................................... 225.0
Net (gain) loss on reacquisition of debt, less taxes..................... (0.2)
-------------- --------------
$ 232.7 $ 384.0
============== ==============
</TABLE>
- ----------
(1) Excludes the conversion of 6% Convertible Subordinated Debentures due 2012
in the amount of approximately $0 and $.7 million at December 31, 1998 and
December 31, 1997, respectively.
(2) These reacquired debentures may be credited against sinking fund
requirements.
(3) Weighted average interest rate of 8.75% and 9.25% in 1998 and 1997,
respectively.
In June 1996, Resources exercised its right to exchange the $130 million
principal amount of its $3.00 Convertible Exchangeable Preferred Stock, Series
A for its 6% Convertible Subordinated Debentures due 2012 (Subordinated
Debentures). The holders of the Subordinated Debentures receive interest
quarterly and have the right at any time on or before the maturity date thereof
to convert each Subordinated Debenture into 0.65 shares of common stock of
Reliant Energy and $14.24 in cash. The Subordinated Debentures are callable
beginning in 1999 at redemption prices beginning at 105.0% and declining to par
in November 2009. Resources is required to make annual sinking fund payments of
$6.5 million on the Subordinated Debentures which began on March 15, 1997 and
will continue on each succeeding March 15 up to and including March 15, 2011.
Resources (i) may credit against the sinking fund requirements any Subordinated
Debentures redeemed by Resources and Subordinated Debentures which have been
converted at the option of the holder and (ii) may deliver purchased
Subordinated Debentures in satisfaction of the sinking fund requirements.
Resources satisfied its 1998 sinking fund requirement of $6.5 million by
delivering Subordinated Debentures purchased in 1996 and 1997.
In February 1998, Resources issued $300 million principal amount of 6.5%
debentures due February 1, 2008. The proceeds from the sale of the debentures
were used to repay short-term indebtedness of Resources, including the
indebtedness incurred in connection with the 1997 purchase of $101 million
aggregate principal amount of its 10% debentures and the repayment of $53
million aggregate principal amount of Resources debt that matured in December
1997 and January 1998. In connection with the issuance of the 6.5% debentures,
Resources received approximately $1 million upon unwinding a $300 million
treasury rate lock agreement, which was tied to the interest rate on 10-year
treasury bonds. The rate lock agreement was executed in January 1998, and
proceeds from the unwind will be amortized over the 10 year life of Resources'
6.5% debentures.
In November 1998, Resources sold $500 million aggregate principal amount
of its 6 3/8% Term Enhanced ReMarketable Securities (TERM Notes). Included
within the TERM Notes is an embedded option sold to an investment bank which
gives the investment bank the right to remarket the TERM Notes in 2003 if it
chooses to exercise the option. The net proceeds of $514 million from the
offering of the TERM Notes were used for general corporate purposes, including
the repayment of (i) $178.5 million of Resources' outstanding commercial paper
and (ii) a $150 million term loan of Resources that matured on November 13,
1998. The TERM Notes are unsecured obligations of Resources which bear interest
at an annual rate of 6 3/8% through November 1, 2003. On November 1, 2003, the
holders of the TERM Notes are required to tender their notes at 100% of their
principal amount. The portion of the proceeds attributable to the option
premium will be amortized over the stated term of the securities. If the option
is not exercised, Resources will repurchase the TERM Notes at 100% of their
principal amount on November 1, 2003. If the option is exercised, the TERM
Notes will be remarketed on a date, selected by Resources, within the 52-week
period beginning November 1, 2003. During such period and prior to remarketing,
the TERM Notes will bear interest at rates, adjusted weekly, based on an index
selected by Resources. If the TERM Notes are
129
<PAGE> 134
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
remarketed, the final maturity date of the TERM Notes will be November 1, 2013,
subject to adjustment, and the effective interest rate on the remarketed TERM
Notes will be 5.66% plus Resources' applicable credit spread at the time of
such remarketing.
(b) Restrictions on Debt.
Under the provisions of the Resources Credit Facility, Resources' total
debt is limited to 55% of its total capitalization. This provision did not
significantly restrict Resources' ability to issue debt or to pay dividends in
1998. At December 31, 1998, Resources' total debt to total capitalization
equaled 40%.
(5) TRUST SECURITIES
In June 1996, a Delaware statutory business trust (Resources Trust)
established by Resources issued in a public offering $172.5 million of
convertible preferred securities and sold approximately $5.3 million of
Resources Trust common stock (106,720 shares, representing 100% of the
Resources Trust's common equity) to Resources. The convertible preferred
securities have a distribution rate of 6.25% payable quarterly in arrears, a
stated liquidation amount of $50 per convertible preferred security and must be
redeemed by 2026. The proceeds from the sale of the preferred and common
securities were used by Resources Trust to purchase $177.8 million of 6.25%
Convertible Junior Subordinated Debentures from Resources having an interest
rate corresponding to the distribution rate of the convertible preferred
securities and a maturity date corresponding to the mandatory redemption date
of the convertible preferred securities. Under existing law, interest payments
made by Resources for the junior subordinated debentures are deductible for
federal income tax purposes. Resources has the right at any time and from time
to time to defer interest payments on the junior subordinated debentures for
successive periods not to exceed 20 consecutive quarters for each such
extension period. In such case, (1) quarterly distributions on the junior
subordinated debentures would also be deferred and (2) Resources has agreed to
not declare or pay any dividend on any common or preferred stock, except in
certain instances.
The Resources Trust is accounted for as a wholly owned consolidated
subsidiary of Resources. The junior subordinated debentures are the sole assets
of the Resources Trust. Resources has fully and unconditionally guaranteed, on
a subordinated basis, the Resources Trust's obligations, including the payment
of distributions and all other payments, with respect to the convertible
preferred securities. The convertible preferred securities are mandatorily
redeemable upon the repayment of the related junior subordinated debentures at
their stated maturity or earlier redemption. Each convertible preferred security
is convertible at the option of the holder into $33.62 of cash and 1.55 shares
of Reliant Energy common stock. During 1998, convertible preferred securities
aggregating $15.5 million were converted, leaving $0.9 million liquidation
amount of convertible preferred securities outstanding at December 31, 1998.
(6) STOCK-BASED INCENTIVE COMPENSATION PLANS AND EMPLOYEE BENEFIT PLANS
(a) Incentive Compensation Plans.
Prior to the Merger, Resources had several incentive compensation plans
which provided for the issuance of stock-based incentives (including restricted
shares, stock options and stock appreciation rights) to directors and key
employees of Resources, including officers. The charge to earnings in 1997 and
1996 related to the incentive compensation plans was $1.4 million and $4.4
million, respectively. All stock options granted under such plans were either
converted into similar Reliant Energy options or "cashed out" prior to the
Merger. All restricted stock and substantially all stock appreciation rights
were "cashed out" with the Merger. Resources granted 463,856 shares of
restricted stock in 1996 with a weighted average fair value at the grant date
of $11.86. At December 31, 1996, there were 77,371 stock appreciation rights
outstanding. As of the Acquisition Date, less than 1,000 stock appreciation
rights were outstanding. The following is certain information relating to
options issued pursuant to Resources' incentive compensation plans.
130
<PAGE> 135
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
WEIGHTED-AVERAGE
NUMBER EXERCISE PRICE
OF SHARES PER SHARE
--------- ---------
<S> <C> <C>
Outstanding at December 31, 1995.............................................. 1,033,019 $ 8.82
Options Granted (2)........................................................... 579,749 $ 8.69
Options Exercised............................................................. (28,019) $ 6.44
Options Forfeited/Expired..................................................... (76,821) $ 11.99
Outstanding at December 31, 1996.............................................. 1,507,928 $ 8.65
Options Exercised............................................................. (147,092) $ 6.47
Options Forfeited/Expired..................................................... (10,682) $ 12.42
Options Cashed Out Upon Merger................................................ (521,857)
Options Converted at Acquisition (1).......................................... (828,297)
Outstanding at December 31, 1997..............................................
Exercisable at:
December 31, 1996............................................................. 911,660 $ 9.48
</TABLE>
- ----------
(1) Effective upon the Merger, each holder of an unexpired Resources stock
option, whether or not then exercisable, was entitled to elect to either
(i) have all or any portion of their Resources stock options canceled and
"cashed out" or (ii) have all or any portion of their Resources stock
options converted to the Reliant Energy stock options. There were 828,297
Resources stock options converted into 622,504 Reliant Energy stock
options at the Acquisition Date.
(2) The weighted average grant date fair value of the options granted in 1996
was $2.39.
In October 1995, the Financial Accounting Standards Board issued SFAS No.
123, "Accounting for Stock-Based Compensation" (SFAS No. 123). SFAS No. 123
provides for the disclosure of certain information concerning the "fair value"
of securities issued pursuant to stock-based employee compensation plans, and
gives Resources the option of calculating and recording compensation expense
utilizing either (i) SFAS No. 123's "fair value" methodology which measures
compensation expense as the "fair value" of all securities at the date on which
they are granted to the employee or (ii) the provisions of Accounting
Principles Board Opinion No. 25, "Accounting for Stock Issued to Employees"
(APB No. 25) which, in general, do not require the recording of compensation
expense for options and stock appreciation rights issued pursuant to plans
structured similarly to those of Resources. Resources elected to continue to
apply the provisions of APB No. 25 for the purpose of computing compensation
expense associated with the relevant plan, although certain additional required
disclosure has been made in accordance with the provisions of SFAS No. 123.
The "fair value" as applied to restricted stock represents the quoted NYSE
closing market price of the shares on the grant date. The term "fair value" as
applied to stock options granted in 1996 and 1995 is a statistical calculation
made utilizing a methodology generally referred to as the Black-Scholes option
pricing model. The model yields a value for each option which is dependent on a
number of variables which are inputs to the relevant calculations. For the
purposes of determining the "fair value" of stock options in the preceding
table, Resources assumed (i) a risk free interest rate (based on U.S. Treasury
strips with a remaining term of five years) of 5.24% to 7.84%, (ii) an expected
option life (duration) of five years, (iii) an expected volatility of 31.6% to
36.4% and (iv) an expected dividend yield of 3.4%. To the extent that actual
conditions during the post-grant, pre-exercise period differ from these
assumptions, the actual value of the options to the employee will differ from
the calculated "fair value" at grant date (see above regarding the effect of
the Merger). Had compensation cost been determined in accordance with the
provisions of SFAS No. 123, the impact on Resources' earnings for 1996 would
have been immaterial.
(b) Employee Benefit Plans.
Resources has two qualified pension plans (the Qualified Plans) which
cover substantially all employees: (1) the plan which covers Resources'
employees other than Reliant Energy Minnegasco employees and (2) the plan which
131
<PAGE> 136
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
covers Reliant Energy Minnegasco employees. The Qualified Plans provide
benefits based on the participants' years of service and highest average
compensation. The funding policy for the Qualified Plans is to contribute at
least the minimum amount required to be funded as determined by Resources'
consulting actuaries. Plan assets are made up of marketable equity and
high-grade fixed income securities.
In addition to the Qualified Plans, Resources maintains certain
non-qualified plans which principally consist of (i) a retirement restoration
plan which allows participants to retain the benefit to which they would have
been entitled under the Qualified Plans except for the federally mandated limits
on such benefits or on the level of salary on which such benefits may be
calculated and (ii) certain supplemental benefit plans which, in the past, were
entered into with individual employees or with small groups of employees.
Participants in these non-qualified plans are general creditors of Resources
with respect to these benefits, as these plans are not funded by Resources in
advance of the cash payment of benefits. The benefit obligation for the
non-qualified plans at December 31, 1998 and 1997 was $37.7 million and $36.3
million, respectively. Expense of approximately $1.7 million, $3.1 million and
$2.0 million associated with these non-qualified plans was recorded during 1998,
1997 and 1996, respectively.
In 1998, Resources adopted SFAS No. 132, "Employers' Disclosures about
Pensions and Other Postretirement Benefits" (SFAS No. 132). SFAS No. 132
revises employers' disclosures about pension and other postretirement benefit
plans. It does not change the measurement or recognition of these plans.
Net Pension cost (qualified plans only) for Resources includes the
following components:
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
------------------------------- -------------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, JULY 31, DECEMBER 31,
1998 1997 1997 1996
---- ---- ---- ----
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Service cost-- benefits earned during the period... $ 13,466 $ 5,095 $ 7,220 $ 11,817
Interest cost on projected benefit obligation...... 33,357 15,015 20,313 29,946
Expected return on plan assets..................... (53,043) (23,856) (26,716) (41,800)
Amortization(1).................................... 66 (641)
---------- ---------- ---------- ----------
Net pension cost (credit).......................... $ (6,220) $ (3,746) $ 883 $ (678)
========== ========== ========== ==========
</TABLE>
- ----------
(1) Amortization after the Acquisition Date represents amortization of
unrecognized loss incurred after the Acquisition Date. For further
discussion of the accounting for the Merger see Note 1(b).
132
<PAGE> 137
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Reconciliations of Resources' beginning and ending balances of its pension
plan benefit obligation, plan assets and funded status for 1998 and 1997 are
set forth below:
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
---------------------------- -------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, JULY 31,
1998 1997 1997
------------- ------------ --------------------
<S> <C> <C> <C>
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of period ........................... $ 513,247 $ 485,206 $ 435,490
Service cost ...................................................... 13,466 5,095 7,220
Interest cost ..................................................... 33,357 15,015 20,313
Benefits paid ..................................................... (23,870) (9,408) (13,340)
Plan amendments ................................................... (53,736)
Actuarial (gain) loss ............................................. 70,746 17,339 35,523
------------ ------------ ------------
Benefit obligation, end of period ................................. 553,210 513,247 485,206
------------ ------------ ------------
CHANGE IN PLAN ASSETS
Plan asset, beginning of period ................................... 569,718 577,275 500,451
Benefits paid ..................................................... (23,870) (9,408) (13,340)
Actual investment return .......................................... 78,514 1,851 90,164
------------ ------------ ------------
Plan assets, end of period ........................................ $ 624,362 $ 569,718 $ 577,275
------------ ------------ ------------
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------
1998 1997
------------ ------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
RECONCILIATION OF FUNDED STATUS
Funded status ....................................................................... $ 71,152 $ 56,471
Unrecognized prior service cost ..................................................... (53,736)
Unrecognized actuarial (gain) loss .................................................. 84,618 39,344
------------ ------------
Net amount recognized at end of year ................................................ $ 102,034 $ 95,815
============ ============
</TABLE>
Resources' Consolidated Balance Sheets included $102 million and $92
million prepaid benefit cost at December 31, 1998 and 1997, respectively.
The assumed rate of increase in future compensation levels utilized in the
above calculations was 3.5% - 5.5% in 1998, 4% - 6% in 1997 and 4% in 1996. The
expected long-term rate of return on fund assets utilized in the above
calculations was 10% for 1998 and 1997. The weighted average discount rate was
6.5% for 1998 and 7.25% for 1997.
In 1998, Reliant Energy's and Resources' board of directors approved an
amendment, effective January 1, 1999, which converted the present value of the
accrued benefits under the existing pension plans into a cash balance plan.
Under the cash balance formula, each participant has an account, for
recordkeeping purposes only, to which credits are allocated annually based on a
percentage of the participant's pay. The applicable percentage is 4%.
The purpose of the plan change is to continue to provide uniform
retirement income benefits across all employee groups, which are competitive
both within the utility industry as well as with other companies within the
United States.
Resources will continue to reflect the costs of the qualified pension plan
according to the provisions of SFAS No. 87 as amended by SFAS No. 132. As a
result of the January 1, 1999 amendment, which is reflected in the December 31,
1998 disclosure, Resources' benefit obligation declined $54 million. The plan
amendment had no impact on 1998 expense.
The actuarial loss is due to changes in certain actuarial assumptions.
Resources has an employee savings plan (the ESP) which covers
substantially all employees other than Reliant Energy Minnegasco employees.
Under the terms of the ESP, employees may contribute up to 12% of total
compensation, of which contributions up to 6% are matched by Resources.
Employer contributions to the ESP of $9.2 million, $9.3 million and $8.9
million were expensed during 1998, 1997 and 1996, respectively. The Reliant
Energy Minnegasco employees are covered by various thrift and profit sharing
plans, the terms of which vary from plan to plan. Expenses of approximately
$1.6 million, $1.5 million and $1.4 million related to these plans were
recorded during 1998, 1997 and 1996, respectively.
Resources records the liability for postretirement benefit plans other
than pensions (primarily health care) under SFAS No. 106, "Employers'
Accounting for Postretirement Benefits Other than Pensions". Resources provides
these benefits under a defined benefit plan for all eligible former employees
who retired prior to July 1, 1992, and under a defined contribution plan for
all others. A substantial number of Resources' employees may become eligible
for postretirement benefits if they are participating in such plans when they
reach normal retirement age. As of December 31, 1998, Resources had contributed
a total of $6 million to an external fund (associated with Reliant Energy
Minnegasco employees) to provide for these benefits. Resources currently
expects that it will fund these benefits utilizing external funding techniques
for additional employees in the future.
133
<PAGE> 138
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The net postretirement benefit cost includes the following components:
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
---------------------------- ----------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, JULY 31, DECEMBER 31,
1998 1997 1997 1996
-------- -------- -------- --------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Service cost-- benefits earned during the period ..... $ 635 $ 115 $ 164 $ 306
Interest cost on accumulated postretirement
benefit obligation ................................ 6,660 3,561 4,948 9,234
Expected return on plan assets ....................... (463) (73) (107) (108)
Net amortization ..................................... 3,875 7,983
-------- -------- -------- --------
Net postretirement benefit cost ...................... $ 6,832 $ 3,603 $ 8,880 $ 17,415
======== ======== ======== ========
</TABLE>
Reconciliations of Resources' beginning and ending balances of its
postretirement benefit plan's benefit obligation, plan assets and funded status
for 1998 and 1997 are set forth below:
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
----------------------------- ----------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, JULY 31,
1998 1997 1997
------------- ------------ ---------------
<S> <C> <C> <C>
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of period ......................... $ 118,472 $ 115,721 $129,381
Service cost .................................................... 635 115 164
Interest cost ................................................... 6,660 3,561 4,948
Benefits paid ................................................... (11,569) (3,543) (7,093)
Participant contributions ....................................... 1,856 568 1,138
Plan amendments ................................................. 28,936
Actuarial (gain) loss ........................................... (921) 2,050 (12,817)
------------ ------------ -------------
Benefit obligation, end of period ............................... 144,069 118,472 115,721
------------ ------------ -------------
CHANGE IN PLAN ASSETS
Plan asset, beginning of period ................................. 4,502 2,909 3,051
Benefits paid ................................................... (11,569) (3,543) (7,093)
Employer contributions .......................................... 11,163 5,171 5,209
Participant contributions ....................................... 1,856 568 1,138
Actual investment return ........................................ 509 (603) 604
------------ ------------ -------------
Plan assets, end of period ...................................... $ 6,461 $ 4,502 $ 2,909
------------ ------------ -------------
YEAR ENDED DECEMBER 31,
-----------------------------
1998 1997
------------ ------------
(THOUSANDS OF DOLLARS)
RECONCILIATION OF FUNDED STATUS
Funded status ................................................... $ (137,608) $ (113,970)
Unrecognized prior service cost ................................. 28,936
Unrecognized actuarial (gain) loss .............................. 1,759 2,726
------------ ------------
Net amount recognized at end of year ............................ $ (106,913) $ (111,244)
============ ============
</TABLE>
Resources' Consolidated Balance Sheets included $107 million and $111
million of postretirement benefit liability at December 31, 1998 and 1997,
respectively.
The weighted average discount rate used in determining the accumulated
benefit obligation for postretirement benefits was 6.50% for 1998, 7.25% for
1997 and 7.5% for 1996. The cost of covered health care benefits (for those
134
<PAGE> 139
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
participants entitled to a defined benefit as a result of having retired prior
to July 1, 1992) is assumed to increase by 6.0% and 6.7% for pre-65 and
post-65, respectively, initially and then increase at a decreasing rate to an
annual and continuing increase of 5.4% by 2001. Based on these assumptions, a
one percentage point increase in the assumed health care cost trend rate would
increase the annual net periodic postretirement benefit cost (before any
deferral for regulatory reasons) and the accumulated benefit obligation at
December 31, 1998 and 1997 by approximately 6.7% and 10.8%, respectively. A one
percentage point decrease in the assumed health care cost trend rate would
decrease the annual net periodic postretirement benefit cost (before any
deferral for regulatory reasons) and the accumulated benefit obligation at
December 31, 1998 by approximately 6.0% and 9.6%, respectively.
In 1998, Reliant Energy's and Resources' boards of directors approved an
amendment, effective January 1, 1999, which created an account balance based on
credited service at December 31, 1998. Under the new plan, each participant has
an account, for recordkeeping purposes only, to which a $750 credit is
allocated annually. This account balance vests after 5 years of service after
age 50. At retirement the account balance can be used to purchase medical
benefits. It may not be taken as cash.
The purpose of the plan change is to continue to provide uniform retiree
medical benefits across all employee groups, which are competitive both within
the utility industry as well as with other companies within the United States.
Resources will continue to reflect the costs of the retiree medical plan
according to the provisions of SFAS No. 106 as amended by SFAS No. 132. As a
result of the January 1, 1999 amendment, which is reflected in the December 31,
1998 disclosure, Resources' benefit obligation increased $29 million. The plan
amendment had no impact on 1998 expense.
The actuarial gain is due to changes in certain actuarial assumptions.
(7) INCOME TAXES
Reliant Energy files a consolidated federal income tax return, in which
Resources and its subsidiaries are included. Prior to the Acquisition Date,
Resources and its subsidiaries filed a consolidated federal income tax return.
Resources' pre-acquisition consolidated federal income tax returns have been
audited and settled through the year 1986. Investment tax credits are generally
deferred and amortized over the lives of the related assets. The unamortized
investment tax credit in deferred credits on Resources' Consolidated Balance
Sheets was $5.8 million and $5.2 million for 1998 and 1997, respectively.
The components of Resources' income tax provision are set forth below:
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
----------------------------- -----------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, JULY 31, DECEMBER 31,
1998 1997 1997 1996
------------ ------------ ------------ ------------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Federal
Current ................................................ $ 30,539 $ (12,005) $ 16,339 $ 33,654
Deferred ............................................... 61,020 36,673 12,795 25,760
Investment tax credit .................................. (609) (262) (363) (636)
State
Current ................................................ 7,235 536 833 4,525
Deferred ............................................... 13,645 (559) 1,794 3,049
------------ ------------ ------------ ------------
Income tax expense ....................................... $ 111,830 $ 24,383 $ 31,398 $ 66,352
============ ============ ============ ============
</TABLE>
135
<PAGE> 140
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The provision for income taxes differs from the amount computed by
applying the statutory federal income tax rate of 35% to income from continuing
operations. The reasons for this difference are as follows:
<TABLE>
<CAPTION>
CURRENT RESOURCES FORMER RESOURCES
------------------------- ------------------------
TWELVE MONTHS FIVE MONTHS SEVEN MONTHS TWELVE MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, JULY 31, DECEMBER 31,
1998 1997 1997 1996
--------- --------- --------- ---------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Income before income taxes ....................... $ 205,654 $ 45,230 $ 77,273 $ 161,490
Statutory rate ................................... 35% 35% 35% 35%
--------- --------- --------- ---------
Income taxes at statutory rate ................... 71,979 15,831 27,046 56,522
--------- --------- --------- ---------
Increase (decrease) in tax
resulting from:
State income taxes, net of ..................... (9) 1,708
federal income tax benefit(1) ............... 14,737 4,923
Investment tax credit .......................... (609) (262) (363) (636)
Research and experimentation ................... (188)
credit
Adjustment to prior-year accruals .............. 2,049 106 (34) 301
Goodwill amortization .......................... 17,971 7,242 2,430 4,163
Other, net ..................................... 5,703 1,475 611 1,267
--------- --------- --------- ---------
Total ........................................ 39,851 8,552 4,352 9,830
========= ========= ========= =========
Income taxes ..................................... $ 111,830 $ 24,383 $ 31,398 $ 66,352
========= ========= ========= =========
Effective Rate ................................... 54.4% 53.9% 40.6% 41.1%
</TABLE>
- ----------
(1) Calculation of the accrual for state income taxes at the end of each year
requires that Resources estimate the manner in which its income for that
year will be allocated and/or apportioned among the various states in
which it conducts business, which states have widely differing tax rules
and rates. These allocation/apportionment factors change from year to year
and the amount of taxes ultimately payable may differ from that estimated
as a part of the accrual process. For these reasons, the amount of state
income tax expense may vary significantly from year-to-year, even in the
absence of significant changes to state income tax valuation allowances or
changes in individual state income tax rates.
136
<PAGE> 141
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The tax effects of temporary differences that gave rise to significant
portions of the deferred tax assets and liabilities as of December 31, 1998 and
1997, were as follows:
<TABLE>
<CAPTION>
DECEMBER 31,
-----------------------------
1998 1997
------------ ------------
(THOUSANDS OF DOLLARS)
<S> <C> <C>
Deferred Tax Assets:
Employee benefit accruals .............................. $ 42,572 $ 53,277
Gas purchase contract accruals ......................... 8,377 8,267
Deferred state income taxes ............................ 14,236 14,460
State operating loss carryforwards ..................... 23,178 29,515
Alternative minimum tax credit carryforwards ........... 39,595 60,669
Other .................................................. 34,698 57,509
Valuation allowance .................................... (8,591) (6,353)
------------ ------------
Total deferred tax assets - net ................ 154,065 217,344
------------ ------------
Deferred Tax Liabilities:
Property, plant and equipment, principally due to
depreciation methods and lives ...................... 539,773 558,758
Deferred gas costs ..................................... 13,663 34,113
Deferred state income taxes ............................ 70,000 70,000
Regulatory obligations ................................. 811 6,690
Other .................................................. 27,580 22,513
------------ ------------
Total deferred tax liabilities ................. 651,827 692,074
------------ ------------
Accumulated deferred income taxes - net .... $ 497,762 $ 474,730
============ ============
</TABLE>
At December 31, 1998, Resources has approximately $368 million of state
net operating losses available to offset future state taxable income through
the year 2013. In addition, Resources has approximately $33 million of federal
alternative minimum tax credits which are available to reduce future federal
income taxes payable, if any, over an indefinite period (although not below the
tentative minimum tax otherwise due in any year), and approximately $2.6
million of state alternative minimum tax credits which are available to reduce
future state income taxes payable, if any, through the year 2001. The valuation
allowance reflects a net increase of $2.3 million in 1998. This net increase
results from a reassessment of Resources' usage of state tax attributes,
including the future ability to use state net operating loss and alternative
minimum tax credit carryforwards, offset by changes in valuation allowances
provided for expiring state net operating loss carryforwards.
137
<PAGE> 142
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(8) COMMITMENTS AND CONTINGENCIES
(a) Lease Commitments.
The following table sets forth certain information concerning Resources'
obligations under operating leases:
<TABLE>
<CAPTION>
Minimum Lease Commitments at December 31, 1998(1)
(millions of dollars)
<S> <C>
1999........................................................................ $ 19
2000........................................................................ 15
2001........................................................................ 14
2002........................................................................ 10
2003........................................................................ 9
2004 and beyond............................................................. 61
----------
Total......................................................................... $ 128
==========
</TABLE>
- ----------
(1) Principally consisting of rental agreements for building space and data
processing equipment and vehicles (including major work equipment);
approximately $16 million represents rental agreements with Reliant
Energy.
Resources has a master leasing agreement which provides for the lease of
vehicles, construction equipment, office furniture, data processing equipment
and other property. For accounting purposes, the lease is treated as an
operating lease. At December 31, 1998, the unamortized value of equipment
covered by the master leasing agreement was $26.9 million. Resources does not
expect to lease additional property under this lease agreement.
Total rental expense for all leases was $25.0 million, $24.0 million and
$33.4 million in 1998, 1997 and 1996, respectively.
(b) Letters of Credit.
At December 31, 1998, Resources had letters of credit incidental to its
ordinary business operations totaling approximately $30 million under which
Resources is obligated to reimburse drawings, if any.
(c) Indemnity Provisions.
At December 31, 1998, Resources had a $5.8 million accounting reserve on
its Consolidated Balance Sheets in "Estimated obligations under indemnification
provisions of sale agreements" for possible indemnity claims asserted in
connection with its disposition of former subsidiaries or divisions, including
the sale of (i) Louisiana Intrastate Gas Corporation, a former subsidiary
engaged in the intrastate pipeline and liquids extraction business (1992); (ii)
Arkla Exploration Company, a former subsidiary engaged in oil and gas
exploration and production activities (June 1991); and (iii) Dyco Petroleum
Company, a former subsidiary engaged in oil and gas exploration and production
(1991).
(d) Sale of Receivables.
Certain of Resources' receivables are collateral for receivables which
have been sold pursuant to the terms of the Receivables Facility. For
information regarding these receivables, see Note 4(a).
138
<PAGE> 143
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(e) Gas Purchase Claims.
In conjunction with settlements of "take-or-pay" claims, Resources has
prepaid for certain volumes of gas, which prepayments have been recorded at
their net realizable value and, to the extent that Resources is unable to
realize at least the carrying amount as the gas is delivered and sold,
Resources' earnings will be reduced, although such reduction is not expected to
be material. In addition to these prepayments, Resources is a party to a number
of agreements which require it to either purchase or sell gas in the future at
prices which may differ from then prevailing market prices or which require it
to deliver gas at a point other than the expected receipt point for volumes to
be purchased. To the extent that Resources expects that these commitments will
result in losses over the contract term, Resources has established reserves
equal to such expected losses. As of December 31, 1998, these reserves were not
material.
(f) Transportation Agreement.
Resources had an agreement (ANR Agreement) with ANR Pipeline Company (ANR)
which contemplated that Resources would transfer to ANR an interest in certain
of Resources' pipeline and related assets. The interest represented capacity of
250 Mmcf/day. Under the ANR Agreement, an ANR affiliate advanced $125 million
to Resources. Subsequently, the parties restructured the ANR Agreement and
Resources refunded in 1995 and 1993, respectively, $50 million and $34 million
to ANR or an affiliate. Resources recorded $41 million as a liability
reflecting ANR's or its affiliates' use of 130 Mmcf/ day of capacity in certain
of Resources' transportation facilities. The level of transportation will
decline to 100 Mmcf/day in the year 2003 with a refund of $5 million to an ANR
affiliate. The ANR Agreement will terminate in 2005 with a refund of the
remaining balance.
(g) Environmental Matters.
To the extent that potential environmental remediation costs are
quantified within a range, Resources establishes reserves equal to the most
likely level of costs within the range and adjusts such accruals as better
information becomes available. In determining the amount of the liability,
future costs are not discounted to their present value and the liability is not
offset by expected insurance recoveries. If justified by circumstances within
Resources' business subject to SFAS No. 71, corresponding regulatory assets are
recorded in anticipation of recovery through the rate making process.
Manufactured Gas Plant Sites. Resources and its predecessors operated a
manufactured gas plant (MGP) adjacent to the Mississippi River in Minnesota
formerly known as Minneapolis Gas Works (FMGW) until 1960. Resources has
substantially completed remediation of the main site other than ongoing water
monitoring and treatment. There are six other former MGP sites in the Minnesota
service territory. Remediation has been completed on one site. Of the remaining
five sites, Resources believes that two were neither owned nor operated by
Resources; two were owned by Resources at one time but were operated by others
and are currently owned by others; and one site was previously owned and
operated by Resources but is currently owned by others. Resources believes it
has no liability with respect to the sites it neither owned nor operated.
At December 31, 1998, Resources had estimated a range of $12 million to
$70 million for possible remediation of the Minnesota sites. The low end of the
range was determined based on only those sites presently owned or known to have
been operated by Resources, assuming use of Resources' proposed remediation
methods. The upper end of the range was determined based on the sites once
owned by Resources, whether or not operated by Resources. The cost estimates of
the FMGW site are based on studies of that site. The remediation costs for the
other sites are based on industry average costs for remediation of sites of
similar size. The actual remediation costs will be dependent upon the number of
sites remediated, the participation of other potentially responsible parties,
if any, and the remediation methods used.
At December 31, 1998 and 1997, Resources had recorded accruals of $5.4
million and $3.3 million, respectively (with a maximum estimated exposure of
approximately $8 million and $18 million at December 31, 1998 and 1997,
respectively) and an offsetting regulatory asset for environmental matters in
connection with a former fire training facility, a landfill and an underground
gas storage facility for which future remediation may be required. This accrual
is in addition to the accrual for MGP sites as previously discussed.
139
<PAGE> 144
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In its 1995 rate case, Reliant Energy Minnegasco was allowed to recover
approximately $7 million annually for remediation costs. In 1998, Reliant
Energy Minnegasco received approval to reduce its annual recovery rate to zero.
Remediation costs are subject to a true-up mechanism whereby any over or under
recovered amounts, net of certain insurance recoveries, plus carrying charges,
would be deferred for recovery or refund in the next rate case. At December 31,
1998 and 1997, Reliant Energy Minnegasco had over recovered $13 million and
$1.8 million, respectively. At December 31, 1998 and 1997, Minnegasco had
recorded a liability of $20.7 million and $21.7 million, respectively, to cover
the cost of future remediation. In addition, at December 31, 1998, Minnegasco
had receivables from insurance settlements of $.6 million. These insurance
settlements will be collected in 1999. Minnegasco expects that approximately
43% of its accrual as of December 31, 1998 will be expended within the next
five years. The remainder will be expended on an ongoing basis for an estimated
40 years. In accordance with the provisions of SFAS No. 71, a regulatory asset
has been recorded equal to the liability accrued. Minnegasco is continuing to
pursue recovery of at least a portion of these costs from insurers. Minnegasco
believes the difference between any cash expenditures for these costs and the
amount recovered in rates during any year will not be material to Resources'
overall cash requirements, results of operations or cash flows.
Issues relating to the identification and remediation of MGPs are common
in the natural gas distribution industry. Resources has received notices from
the United States Environmental Protection Agency (EPA) and others regarding
its status as a potentially responsible party (PRP) for other sites. Based on
current information, Resources has not been able to quantify a range of
environmental expenditures for potential remediation expenditures with respect
to other MGP sites.
Mercury Contamination. Like other natural gas pipelines, Resources'
pipeline operations have in the past employed elemental mercury in meters used
on its pipelines. Although the mercury has now been removed from the meters, it
is possible that small amounts of mercury have been spilled at some of those
sites in the course of normal maintenance and replacement operations and that
such spills have contaminated the immediate area around the meters with
elemental mercury. Such contamination has been found by Resources at some sites
in the past, and Resources has conducted remediation at sites found to be
contaminated. Although Resources is not aware of additional specific sites, it
is possible that other contaminated sites exist and that remediation costs will
be incurred for such sites. Although the total amount of such costs cannot be
known at this time, based on experience by Resources and others in the natural
gas industry to date and on the current regulations regarding remediation of
such sites, Resources believes that the cost of any remediation of such sites
will not be material to Resources' financial position, results of operation or
cash flows.
Potentially Responsible Party Notifications. From time to time Resources
and its subsidiaries have been notified that they are PRP's with respect to
properties which environmental authorities have determined warrant remediation
under state or federal environmental laws and regulations. In October 1994 the
EPA issued such a notice with respect to the South 8th Street landfill site in
West Memphis, Arkansas, and in December 1995, the Louisiana Department of
Environmental Quality advised that one of Resources' subsidiaries had been
identified as a PRP with respect to a hazardous waste site in Shreveport,
Louisiana.
In 1998, MRT received a notice of potential liability from the EPA
regarding MRT's PRP status with respect to the Gurley Pit Superfund Site. The
notice stated that MRT is a PRP for the response costs at this site because MRT
allegedly generated materials that were disposed of at the site. MRT
subsequently notified the EPA that it does not believe that it has liability
because it did not have operations in the state from which the material was
allegedly hauled. In December 1998, MRT learned that the South 8th Street
Superfund Site Group and the EPA reached a tentative settlement regarding the
South 8th Street and Gurley Pit Superfund Sites.
140
<PAGE> 145
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Considering the information currently known about such sites and the
involvement of Resources or its subsidiaries in activities at these sites,
Resources does not believe that these matters will have a material adverse
effect on Resources' financial position, results of operation or cash flows.
Resources 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 Resources' Consolidated Financial Statements, if any, from
the disposition of these matters will not be material.
(9) REPORTABLE SEGMENTS
Effective January 1, 1998, Resources adopted SFAS No. 131, "Disclosures
about Segments of an Enterprise and Related Information" (SFAS No. 131).
Because Resources is a wholly owned subsidiary of Reliant Energy, Resources'
determination of reportable segments considers the strategic operating units
under which Reliant Energy manages sales of various products and services to
wholesale or retail customers in differing regulatory environments. Subsequent
to the Acquisition Date, segment financial data includes information for Reliant
Energy and Resources on a combined basis, except for Electric Operations which
has no Resources operations and International, which has minimal Resources
operations. Reconciling items included under the caption "Elimination of
Non-Resources Operations" reduce the consolidated Reliant Energy amounts by
those operations not conducted within the Resources legal entity. Operations not
owned or operated by Resources, but included in segment information before
elimination include primarily the operations and assets of Reliant Energy's
non-rate regulated power generation business, Reliant Energy's investment in
Time Warner securities and non-Resources corporate expenses. The determination
of reportable segments under SFAS No. 131 differs from that required in prior
years; therefore business segment information for 1997 and 1996 has been
restated to comply with SFAS No. 131.
The accounting policies of the segments are the same as those described in
the summary of significant accounting policies except that certain executive
benefit costs have not been allocated to segments. Reliant Energy evaluates
performance based on operating income excluding certain corporate costs not
allocated to the segments. Reliant Energy and Resources account for
intersegment sales as if the sales were to third parties, that is, at current
market prices.
In accordance with SFAS No. 131, Reliant Energy has identified the
following reportable segments: Electric Operations, Natural Gas Distribution,
Interstate Pipelines, Wholesale Energy, International and Corporate. Natural Gas
Distribution operations consist of natural gas sales to, and natural gas
transportation for, residential, commercial and certain industrial customers.
Interstate Pipelines conducts interstate natural gas pipeline operations.
Wholesale Energy is engaged in the acquisition, development and operation of
non-utility power generation facilities, as well as the wholesale energy
marketing and natural gas gathering businesses. Corporate includes the Reliant
Energy's and Resources' unregulated retail electric services business, certain
real estate holdings of Reliant Energy and corporate costs.
141
<PAGE> 146
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Financial data for business segments and products and services are as
follows:
<TABLE>
<CAPTION>
NATURAL GAS INTERSTATE WHOLESALE CORPORATE RECONCILING
DISTRIBUTION PIPELINES ENERGY AND OTHER ELIMINATIONS
------------ ----------- ----------- ----------- ------------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C> <C>
Current Resources
As of and for the Year Ended
December 31, 1998:
Revenues from external customers ....... $ 1,811,509 $ 126,988 $ 4,289,006 $ 651,741
----------- ----------- ----------- -----------
Intersegment revenues .................. 1,167 155,508 167,152 97,181 $ (421,008)
Depreciation and amortization .......... 129,777 44,025 18,204 10,527
Operating income ....................... 137,955 128,328 59,170 (43,751)
Total assets ........................... 3,110,718 2,050,636 1,535,007 1,710,920 (915,895)
Equity investments in and advances to
unconsolidated subsidiaries ............ 42,252
Expenditures for additions to
long-lived assets ...................... 161,735 59,358 365,512 28,077
Current Resources
As of and for the Five Months Ended
December 31, 1997:
Revenues from external customers ....... 892,064 49,655 1,288,357 304,878
Intersegment revenues .................. 505 58,678 76,301 34,853 (170,337)
Depreciation and amortization .......... 51,883 19,088 2,633 6,260
Operating income ....................... 54,502 31,978 912 (37,340)
Total assets ........................... 3,073,525 2,031,879 777,638 1,749,916 (597,686)
Equity investments in and advances to
unconsolidated subsidiaries ............ 3,325
Expenditures for additions to
long-lived assets ...................... 61,078 16,304 14,038 23,899
Former Resources
For the Seven Months Ended
July 31, 1997:
Revenues from external customers ....... 1,309,060 86,465 1,589,032 329,034
Intersegment revenues .................. 672 100,246 88,188 35,285 (224,391)
Depreciation and amortization .......... 56,626 17,230 1,629 9,416
Operating income ....................... 111,934 76,730 (13,262) (20,362)
Expenditures for additions to
long-lived assets ...................... 69,422 9,619 8,996 7,025
Former Resources
As of and for the Year Ended
December 31, 1996
Revenue from external customers ........ 2,112,303 144,752 2,017,599 513,808
Intersegment revenues .................. 1,286 200,510 178,005 41,141 (420,942)
Depreciation and amortization .......... 94,853 29,172 2,113 16,224
Operating income ....................... 178,141 107,903 25,978 2,444
Expenditures for additions to
long-lived assets ...................... 116,400 39,900 10,200 10,657
</TABLE>
<TABLE>
<CAPTION>
ELIMINATION OF
NON-RESOURCES
OPERATIONS CONSOLIDATED
-------------- ------------
<S> <C> <C>
Current Resources
As of and for the Year Ended
December 31, 1998:
Revenues from external customers ....... $ (120,832) $ 6,758,412
----------- -----------
Intersegment revenues ..................
Depreciation and amortization .......... (10,642) 191,891
Operating income ....................... 28,603 310,305
Total assets ........................... (835,865) 6,655,521
Equity investments in and advances to
unconsolidated subsidiaries ............ (42,252)
Expenditures for additions to
long-lived assets ...................... (368,778) 245,904
Current Resources
As of and for the Five Months Ended
December 31, 1997:
Revenues from external customers ....... (8,772) 2,526,182
Intersegment revenues ..................
Depreciation and amortization .......... (1,777) 78,087
Operating income ....................... 40,704 90,756
Total assets ........................... (873,434) 6,161,838
Equity investments in and advances to
unconsolidated subsidiaries ............ (3,325)
Expenditures for additions to
long-lived assets ...................... (20,826) 94,493
Former Resources
For the Seven Months Ended
July 31, 1997:
Revenues from external customers ....... 3,313,591
Intersegment revenues ..................
Depreciation and amortization .......... 84,901
Operating income ....................... 155,040
Expenditures for additions to
long-lived assets ...................... 95,062
Former Resources
As of and for the Year Ended
December 31, 1996
Revenue from external customers ........ 4,788,462
Intersegment revenues ..................
Depreciation and amortization .......... 142,362
Operating income ....................... 314,466
Expenditures for additions to
long-lived assets ...................... 177,157
</TABLE>
- ----------
(1) Includes data for operations conducted and assets owned at the parent
corporation level. This data is eliminated for purposes of the
consolidated data.
142
<PAGE> 147
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Reconciliation of Operating Income to Net Income:
<TABLE>
<CAPTION>
CURRENT RESOURCES CURRENT RESOURCES FORMER RESOURCES FORMER RESOURCES
------------------ ------------------ ------------------ -----------------
FIVE MONTHS SEVEN MONTHS YEAR ENDED
YEAR ENDED ENDED DECEMBER ENDED JULY 31, DECEMBER 31,
DECEMBER 31, 1998 31, 1997 1997 1996
------------------ ------------------ ------------------ -----------------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Operating income...................... $ 310,305 $ 90,756 $ 155,040 $ 314,466
Interest expense...................... (111,337) (47,490) (78,660) (132,557)
Distribution on trust securities...... (632) (279) (6,317)
Preferred dividends of subsidiary..... (5,842)
Income taxes.......................... (111,830) (24,383) (31,398) (66,352)
Other income (expense)................ 7,318 2,243 7,210 (18,857)
------------------ ------------------ ------------------ -----------------
Net income............................ $ 93,824 $ 20,847 $ 45,875 $ 90,858
================== ================== ================== =================
</TABLE>
Revenues by Products and Services:
<TABLE>
<CAPTION>
CURRENT RESOURCES CURRENT RESOURCES FORMER RESOURCES FORMER RESOURCES
------------------ ------------------ ------------------ -----------------
FIVE MONTHS SEVEN MONTHS YEAR ENDED
YEAR ENDED ENDED DECEMBER ENDED JULY 31, DECEMBER 31,
DECEMBER 31, 1998 31, 1997 1997 1996
------------------ ------------------ ------------------ -----------------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Retail power sales.................... $ 9,582 $ 2,650 $ 1,805 $ 407
Retail gas sales...................... 2,362,504 1,153,968 1,595,480 2,570,708
Wholesale energy and energy related
sales................................. 4,248,181 1,271,746 1,562,842 1,975,400
Gas transport......................... 167,812 66,265 112,655 186,952
Energy products and services.......... 91,165 40,325 40,809 54,995
Elimination of non-Resources
operations............................ (120,832) (8,772)
------------------ ------------------ ------------------ -----------------
Total................................. $ 6,758,412 $ 2,526,182 $ 3,313,591 $ 4,788,462
================== ================== ================== =================
</TABLE>
143
<PAGE> 148
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(10) ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------------------------------------------
1998 1997
------------------------------ ------------------------------
CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE
------------- ------------ ------------- -------------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Financial Assets of Resources:
Energy Derivatives - non-trading.......... $ $ $ 9,399 $ 13,060
Financial Liabilities of Resources:
Long-term debt............................. 1,513,289 1,746,641 1,148,848 1,147,344
Trust preferred securities................. 1,157 1,467 21,290 24,569
Energy Derivatives - non-trading........... 8,166
Interest rate swaps........................ 755
</TABLE>
The fair values of cash and short-term investments, marketable equity
securities, short-term and other notes payable are estimated to be equivalent
to carrying amounts. The remaining fair values have been determined using
quoted market prices of the same or similar securities when available or other
estimation techniques.
The fair value of financial instruments included in the trading operations
of Reliant Energy Services are marked-to-market at December 31, 1998 (see Note
2). Therefore, they are stated at fair value and are excluded from the table
above.
(11) UNAUDITED QUARTERLY INFORMATION
The following unaudited quarterly financial information includes, in the
opinion of management, all adjustments (which comprise only normal recurring
accruals) necessary for a fair presentation. Quarterly results are not
necessarily indicative of a full year's operations because of seasonality and
other factors, including rate increases and variations in operating expense
patterns.
The Merger was recorded under the purchase method of accounting, resulting
in new carrying values for certain of Resources' assets, liabilities and equity
based on preliminary analysis. The new basis is reflected in Resources'
Consolidated Financial Statements beginning with the Acquisition Date. (For
additional information; see Note 1(b).)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, 1998
---------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER(1) QUARTER(1) QUARTER(1) QUARTER(1)
----------- ----------- ----------- -----------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C>
Operating Revenues................................... $ 1,754,524 $ 1,380,488 $ 1,927,120 $ 1,696,280
Operating Income (loss).............................. 143,494 15,734 23,653 127,424
Net income (loss)(2)................................. $ 61,827 $ (4,872) $ (2,586) $ 39,455
</TABLE>
144
<PAGE> 149
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, 1997
----------------------------------------------------------------------
FORMER RESOURCES CURRENT RESOURCES
---------------------------------------- --------------------------
ONE MONTH TWO MONTHS
ENDED ENDED
FIRST JULY 31, SEPTEMBER 30, FOURTH
QUARTER SECOND QUARTER 1997 1997 QUARTER
------------ -------------- ---------- ------------ ----------
(THOUSANDS OF DOLLARS)
<S> <C> <C> <C> <C> <C>
Operating Revenues................................... $ 1,898,851 $1,017,232 $ 397,508 $ 748,915 $1,777,267
Operating Income (loss)(4) .......................... 145,221 36,616 (26,797) 10,781 79,975
Income (loss) before
extraordinary item ............................... 68,410 702 (23,237) (6,646) 27,493
Extraordinary item, less taxes(3) ................... 237
Net income (loss)(4)................................. $ 68,647 $ 702 $ (23,237) $ (6,646) $ 27,493
</TABLE>
- ----------
(1) First, second and third quarter of 1998 have been restated for the change
in accounting principle to mark-to-market accounting. For further
discussion see Note 1(r).
(2) Before preferred dividend requirement.
(3) Net gain (loss) on early retirement of debt, less taxes.
(4) Includes a pre-tax charge of $22.3 million associated with early
retirement and severance costs.
145
<PAGE> 150
INDEPENDENT AUDITORS' REPORT
Reliant Energy Resources Corp.:
We have audited the accompanying consolidated balance sheets of Reliant
Energy Resources Corp. (formerly NorAm Energy Corp.) and its subsidiaries
(Resources) as of December 31, 1998 and 1997, and the related statements of
consolidated income, consolidated stockholders' equity and comprehensive income
and consolidated cash flows for the year ended December 31, 1998, the five
months ended December 31, 1997 and the seven months ended July 31, 1997. Our
audits also included the Resources' financial statement schedule listed in Item
14(a)(4) for the years ended December 31, 1998 and 1997. These financial
statements and the financial statement schedule are the responsibility of
Resources' management. Our responsibility is to express an opinion on these
financial statements and the financial statement schedule based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, such consolidated financial statements present fairly, in
all material respects, the financial position of Reliant Energy Resources Corp.
and its subsidiaries at December 31, 1998 and 1997, and the results of their
operations and their cash flows for the year ended December 31, 1998, the five
months ended December 31, 1997 and the seven months ended July 31, 1997 in
conformity with generally accepted accounting principles. Also, in our opinion,
such financial statement schedule, when considered in relation to the basic
consolidated financial statements taken as a whole, presents fairly in all
material respects the information set forth therein.
DELOITTE & TOUCHE LLP
Houston, Texas
February 25, 1999
146
<PAGE> 151
REPORT OF INDEPENDENT ACCOUNTANTS
Reliant Energy Resources Corp.
We have audited the consolidated statements of income, cash flows and
change in stockholders' equity and comprehensive income and the financial
statement schedule of Reliant Energy Resources Corp. and Subsidiaries
(Resources) as of December 31, 1996 and for the year then ended as listed in
Item 14(a)(2) and Item 14(a)(4) of this Form 10-K. These financial statements
and the financial statement schedule are the responsibility of Resources'
management. Our responsibility is to express an opinion on these financial
statements and the financial statement schedule based on our audit.
We conducted our audit in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audit provides a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the consolidated results of Resources' operations and
their cash flows for the year ended December 31, 1996 in conformity with
general accepted accounting principles. In addition, in our opinion, the
financial statement schedule referred to above, when considered in relation to
the basic financial statements taken as a whole, presents fairly, in all
material respects, the information required to be included therein.
COOPERS & LYBRAND L.L.P.
Houston, Texas
March 25, 1997
147
<PAGE> 152
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY AND RESOURCES.
(a) The Company. The information called for by Item 10, to the extent not
set forth under Item 1 "Business --Executive Officers of the Company," is or
will be set forth in the definitive proxy statement relating to the Company's
1999 annual meeting of shareholders pursuant to the Commission's Regulation
14A. Such definitive proxy statement relates to a meeting of shareholders
involving the election of directors and the portions thereof called for by Item
10 are incorporated herein by reference pursuant to Instruction G to Form 10-K.
(b) Resources. The information called for by Item 10 with respect to
Resources is omitted pursuant to Instruction I(2)(a) to Form 10-K (Omission of
Information by Certain Wholly-Owned Subsidiaries).
ITEM 11. EXECUTIVE COMPENSATION.
(a) The Company. The information called for by Item 11 is or will be set
forth in the definitive proxy statement relating to the Company's 1999 annual
meeting of shareholders pursuant to the Commission's Regulation 14A. Such
definitive proxy statement relates to a meeting of shareholders involving the
election of directors and the portions thereof called for by Item 11 are
incorporated herein by reference pursuant to Instruction G to Form 10-K.
(b) Resources. The information called for by Item 11 with respect to
Resources is omitted pursuant to Instruction I(2)(a) to Form 10-K (Omission of
Information by Certain Wholly-Owned Subsidiaries).
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.
(a) The Company. The information called for by Item 12 is or will be set
forth in the definitive proxy statement relating to the Company's 1999 annual
meeting of shareholders pursuant to the Commission's Regulation 14A. Such
definitive proxy statement relates to a meeting of shareholders involving the
election of directors and the portions thereof called for by Item 12 are
incorporated herein by reference pursuant to Instruction G to Form 10-K.
(b) Resources. The information called for by Item 12 with respect to
Resources is omitted pursuant to Instruction I(2)(a) to Form 10-K (Omission of
Information by Certain Wholly-Owned Subsidiaries).
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
(a) The Company. The information called for by Item 13 is or will be set
forth in the definitive proxy statement relating to the Company's 1999 annual
meeting of shareholders pursuant to the Commission's Regulation 14A. Such
definitive proxy statement relates to a meeting of shareholders involving the
election of directors and the portions thereof called for by Item 13 are
incorporated herein by reference pursuant to Instruction G to Form 10-K.
(b) Resources. The information called for by Item 13 with respect to
Resources is omitted pursuant to Instruction I(2)(a) to Form 10-K (Omission of
Information by Certain Wholly-Owned Subsidiaries).
148
<PAGE> 153
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K.
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
(a)(1) Company Financial Statements.
Statements of Consolidated Income for the Three Years Ended December 31, 1998.............................. 58
Statements of Consolidated Retained Earnings and Comprehensive Income for the
Three Years Ended December 31, 1998...................................................................... 59
Consolidated Balance Sheets at December 31, 1998 and 1997.................................................. 60
Consolidated Statements of Capitalization at December 31, 1998 and 1997.................................... 62
Statements of Consolidated Cash Flows for the Three Years Ended December 31, 1998.......................... 65
Notes to Consolidated Financial Statements................................................................. 67
Independent Auditors' Report - Company..................................................................... 108
(a)(2) Resources Financial Statements.
Statements of Consolidated Income for the Year Ended December 31, 1998, the Five Months Ended
December 31, 1997, the Seven Months Ended July 31, 1997 and the Year Ended December 31, 1996............. 113
Consolidated Statements of Stockholder's Equity and Comprehensive Income for the Year Ended
December 31, 1998, the Five Months Ended December 31, 1997, the Seven Months Ended July 31, 1997
and the Year Ended December 31, 1996..................................................................... 114
Consolidated Balance Sheets at December 31, 1998 and 1997................................................... 115
Statements of Consolidated Cash Flows for the Year Ended December 31, 1998, the Five Months Ended
December 31, 1997, the Seven Months Ended July 31, 1997 and the Year Ended December 31, 1996............. 117
Notes to Consolidated Financial Statements.................................................................. 119
Independent Auditors' Reports - Resources................................................................... 146
(a)(3) Company Financial Statement Schedules For The Three Years Ended December 31, 1998.
THE COMPANY:
II-- Reserves.............................................................................................. 150
(a)(4) Resources Financial Statement Schedules For The Three Years Ended December 31, 1998.
RESOURCES:
II-- Reserves.............................................................................................. 151
The following schedules are omitted for each of the Company and Resources because of the absence
of the conditions under which they are required or because the required information is included in
the financial statements:
I, III, IV and V.
(a)(5) Exhibits............................................................................................ 155
See Index of Exhibits for the Company (page 155) and Resources (page 169), which indexes also
include the management contracts or compensatory plans or arrangements required to be filed as
exhibits to this Form 10-K by Item
601(10)(iii) of Regulation S-K.
(b) Reports on Form 8-K.
THE COMPANY:
Form 8-K (Item 5) dated October 13, 1998, and filed on October 31, 1998
Form 8-K (Item 5) dated January 26, 1999, and filed February 1, 1999
Form 8-K (Item 5) dated February 23, 1999, and filed February 26, 1999
RESOURCES:
Form 8-K (Item 5) dated November 5, 1998, and filed on November 11, 1998
</TABLE>
149
<PAGE> 154
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
SCHEDULE II -- RESERVES
FOR THE THREE YEARS ENDED DECEMBER 31, 1998
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
COLUMN C
-----------------------
COLUMN B ADDITIONS COLUMN D COLUMN E
COLUMN A ----------- ----------------------- ---------- -----------
------------------------------------------- BALANCE AT CHARGED CHARGED DEDUCTIONS BALANCE AT
BEGINNING TO TO OTHER FROM END
DESCRIPTION OF PERIOD INCOME ACCOUNTS RESERVES OF PERIOD
--------------------------------------------------------- ---------- ---------- ---------- -----------
<S> <C> <C> <C> <C> <C>
Year Ended December 31, 1998:
Accumulated provisions deducted from
related assets on balance sheet:
Uncollectible accounts................... $15,344 $10,018 $10,931 $14,431
Reserves other than those deducted from
assets on balance sheet:
Property insurance....................... (3,567) 2,187 3,573 (4,953)
Injuries and damages..................... 3,181 2,724 3,408 2,497
Non-regulated project contingencies...... 1,780 693 2,273 200
Year Ended December 31, 1997:
Accumulated provisions deducted from
related assets on balance sheet:
Uncollectible accounts................... 5,625 $15,404 5,685 15,344
Uncollectible advances................... 33,159 33,159 0
Reserves other than those deducted from
assets on balance sheet:
Property insurance....................... 70 2,187 5,824 (3,567)
Injuries and damages..................... 1,128 5,215 3,162 3,181
Non-regulated project contingencies...... 2,296 516 1,780
Year Ended December 31, 1996:
Accumulated provisions deducted from
related assets on balance sheet:
Uncollectible advances................... 27,412 5,015 732 33,159
Reserves other than those deducted from
assets on balance sheet:
Property insurance....................... (2,117) 2,187 70
Injuries and damages..................... 1,523 3,156 3,551 1,128
Non-regulated project contingencies...... 2,929 (633) 2,296
</TABLE>
- ----------
Notes:
(a) Deductions from reserves represent losses or expenses for which the
respective reserves were created. In the case of the uncollectible
accounts reserve, such deductions are net of recoveries of amounts
previously written off.
(b) Charged to other account represents the provision for uncollectible
accounts acquired in the August 1997 merger with Resources.
150
<PAGE> 155
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
SCHEDULE II -- RESERVES
FOR THE THREE YEARS ENDED DECEMBER 31, 1998
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
COLUMN C
--------------------------
COLUMN B ADDITIONS COLUMN D COLUMN E
COLUMN A ------------- -------------------------- ------------- -------------
--------------------------------------------- BALANCE AT CHARGED CHARGED DEDUCTIONS BALANCE AT
BEGINNING TO TO OTHER FROM END
DESCRIPTION OF PERIOD INCOME ACCOUNTS RESERVES OF PERIOD
----------------------------------------------------------- -------------------------- ------------- -------------
<S> <C> <C> <C> <C> <C>
Reserves which are deducted in the balance
sheet from assets to which they apply:
(a) Allowance for Doubtful Accounts
Receivable
Year ended December 31, 1998............ $15,344 $10,018 $10,931 $14,431
Year ended December 31, 1997............ $13,023 $13,245 $2,383 $13,307 $15,344
Year ended December 31, 1996............ $11,117 $12,364 $3,189 $13,647 $13,023
(b) Deferred Tax Assets Valuation Allowance
Year ended December 31, 1998............ $ 6,353 $ 2,238 $ 8,591
Year ended December 31, 1997............ $ 6,761 $ 2,539 $ 2,947 $ 6,353
Year ended December 31, 1996............ $ 6,188 $ 573 $ 6,761
</TABLE>
- ----------
Notes:
(a) Deductions from reserves represent losses or expenses for which the
respective reserves were created. In the case of the uncollectible
accounts reserve, such deductions are net of recoveries of amounts
previously written off.
151
<PAGE> 156
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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, in the City of
Houston and State of Texas, on the 18th day of March, 1999.
HOUSTON INDUSTRIES INCORPORATED
(Registrant)
By: /s/ DON D. JORDAN
----------------------------
Don D. Jordan
Chairman and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities indicated on March 18, 1999.
SIGNATURE TITLE
- ----------------------------- ----------------------------------------
/s/ DON D. JORDAN Chairman and Chief Executive Officer and
- ----------------------------- Director
(Don D. Jordan) (Principal Executive Officer)
/s/ STEPHEN W. NAEVE Executive Vice President and Chief
- ----------------------------- Financial Officer
(Stephen W. Naeve) (Principal Financial Officer)
/s/ MARY P. RICCIARDELLO Vice President and Comptroller
- -----------------------------
(Mary P. Ricciardello) (Principal Accounting Officer)
/s/ JAMES A. BAKER Director
- -----------------------------
(James A. Baker)
/s/ RICHARD E. BALZHISER Director
- -----------------------------
(Richard E. Balzhiser)
/s/ MILTON CARROLL Director
- -----------------------------
(Milton Carroll)
/s/ JOHN T. CATER Director
- -----------------------------
(John T. Cater)
/s/ O. HOLCOMBE CROSSWELL Director
- -----------------------------
(O. Holcombe Crosswell)
/s/ ROBERT J. CRUIKSHANK Director
- -----------------------------
(Robert J. Cruikshank)
/s/ LINNET F. DEILY Director
- -----------------------------
(Linnet F. Deily)
152
<PAGE> 157
/s/ JOSEPH M. GRANT Director
- -----------------------------
(Joseph M. Grant)
/s/ ROBERT C. HANNA Director
- -----------------------------
(Robert C. Hanna)
/s/ LEE W. HOGAN Director
- -----------------------------
(Lee W. Hogan)
/s/ T. MILTON HONEA Director
- -----------------------------
(T. Milton Honea)
/s/ R. STEVE LETBETTER Director
- -----------------------------
(R. Steve Letbetter)
/s/ ALEXANDER F. SCHILT Director
- -----------------------------
(Alexander F. Schilt)
/s/ BERTRAM WOLFE Director
- -----------------------------
(Bertram Wolfe)
153
<PAGE> 158
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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, in the City of
Houston and State of Texas, on the 18th day of March, 1999.
RELIANT ENERGY RESOURCES CORP.
(Registrant)
By: /s/ DON D. JORDAN
------------------------------------
Don D. Jordan
Chairman and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities indicated on March 18, 1999.
SIGNATURE TITLE
- ----------------------------- ----------------------------------
/s/ DON D. JORDAN Chairman and Chief Executive Officer
- ----------------------------- (Principal Executive Officer and
(Don D. Jordan) Principal Financial Officer)
/s/ MARY P. RICCIARDELLO Vice President and Comptroller
- ----------------------------- (Principal Accounting Officer)
(Mary P. Ricciardello)
/s/ STEPHEN W. NAEVE Sole Director
- -----------------------------
(Stephen W. Naeve)
154
<PAGE> 159
HOUSTON INDUSTRIES INCORPORATED
D/B/A RELIANT ENERGY, INCORPORATED
RELIANT ENERGY RESOURCES CORP.
EXHIBITS TO THE COMBINED ANNUAL REPORT ON FORM 10-K
FOR FISCAL YEAR ENDED DECEMBER 31, 1998
INDEX OF EXHIBITS
Exhibits not incorporated by reference to a prior filing are designated by
a cross (+); all exhibits not so designated are incorporated herein by
reference to a prior filing as indicated. Exhibits designated by an asterisk
(*) are management contracts or compensatory plans or arrangements required to
be filed as exhibits to this Form 10-K by Item 601(10)(iii) of Regulation S-K.
(A) HOUSTON INDUSTRIES INCORPORATED
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
2(a)(1) Agreement and Plan of Merger among HI's Form 8-K dated August 1-7629 2
the Company, Houston Lighting & 11, 1996
Power ("HL&P"), HI Merger, Inc. and
NorAm dated August 11, 1996
2(a)(2) Amendment to Agreement and Plan of Registration Statement on 333-11329 2(c)
Merger among the Company, HL&P, HI Form S-4
Merger, Inc. and NorAm dated August
11, 1996
3(a) Restated Articles of Incorporation Form 10-K for the year 1-3187 3(a)
of the Company, restated as of ended December 31, 1997
September 1997
3(b) Amended and Restated Bylaws of the Form 10-Q for the quarter 1-3187 3
Company, as of September 1998 ended September 30, 1998
3(c) Statement of Resolution Form 10-Q for the quarter 1-3187 3
Establishing Series of Shares ended March 31, 1998
designated Series C Preference Stock
4(a)(1) Mortgage and Deed of Trust, dated Form S-7 of HL&P filed on 2-59748 2(b)
November 1, 1944 between HL&P and August 25, 1977
Chase Bank of Texas, National
Association (formerly, South Texas
Commercial National Bank of
Houston), as Trustee as amended and
supplemented by 20 Supplemental
Indentures thereto
</TABLE>
155
<PAGE> 160
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
4(a)(2) Twenty-First through Fiftieth HL&P's Form 10-K for the 1-3187 4(a)(2)
Supplemental Indentures to Exhibit year ended December 31, 1989
4(a)(1)
4(a)(3) Fifty-First Supplemental Indenture HL&P's Form 10-Q for the 1-3187 4(a)
to Exhibit 4(a)(1) dated as of quarter ended June 30, 1991
March 25, 1991
4(a)(4) Fifty-Second through Fifty-Fifth HL&P's Form 10-Q for the 1-3187 4
Supplemental Indentures to Exhibit quarter ended March 31, 1992
4(a)(1) each dated as of March 1,
1992
4(a)(5) Fifty-Sixth and Fifty-Seventh HL&P's Form 10-Q for the 1-3187 4
Supplemental Indentures to Exhibit quarter ended September 30,
4(a)(1) each dated as of October 1, 1992
1992
4(a)(6) Fifty-Eighth and Fifty-Ninth HL&P's Form 10-Q for the 1-3187 4
Supplemental Indentures to Exhibit quarter ended March 31, 1993
4(a)(1) each dated as of March 1,
1993
4(a)(7) Sixtieth Supplemental Indenture to HL&P's Form 10-Q for the 1-3187 4
Exhibit 4(a)(1) dated as of July 1, quarter ended June 30, 1993
1993
4(a)(8) Sixty-First through Sixty-Third HL&P's Form 10-K for the 1-3187 4(a)(8)
Supplemental Indentures to Exhibit year ended December 31, 1993
4(a)(1) each dated as of December
1, 1993
4(a)(9) Sixty-Fourth and Sixty-Fifth HL&P's Form 10-K for the 1-3187 4(a)(9)
Supplemental Indentures to Exhibit year ended December 31, 1995
4(a)(1) each dated as of July 1,
1995
4(a)(10) Junior Subordinated Trust Debenture HL&P's Form 8-K dated 1-3187 4.1
Indenture, dated as of February 1, February 4, 1997
1997, between the Company and The
Bank of New York, as Trustee
</TABLE>
156
<PAGE> 161
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
4(a)(11) Supplemental Indenture No. 1 to HL&P's Form 8-K dated 1-3187 4.2-A
Junior Subordinated Indenture, February 4, 1997
dated as of February 1, 1997,
providing for issuance of the
Company's 8.125% Junior
Subordinated Deferrable Interest
Debentures, Series A due March 31,
2046, including form of 8.125%
junior subordinated interest
debenture, Series A
4(a)(12) Supplemental Indenture No. 2 to HL&P's Form 8-K dated 1-3187 4.2-B
Junior Subordinated Indenture, February 4, 1997
dated as of February 1, 1997,
providing for issuance of 8.257%
Junior Subordinated Deferrable
Interest Debentures, Series B (due
February 1, 2037), including form
of junior subordinated interest
debenture, Series B
4(a)(13) Amended and Restated Trust HL&P's Form 8-K dated 1-3187 4.3-A
Agreement, dated as of February 4, February 4, 1997
1997, of HL&P Capital Trust I,
including form of Preferred
Security and Agreement as to
Expenses and Liabilities
4(a)(14) Amended and Restated Trust HL&P's Form 8-K dated 1-3187 4.3-B
Agreement, dated as of February 4, February 4, 1997
1997, of HL&P Capital Trust II,
including form of Capital Security
of HL&P Capital Trust II and
Agreement as to Expenses and
Liabilities
4(a)(15) Guarantee Agreement relating to HL&P's Form 8-K dated 1-3187 4.6-A
Capital Trust I dated as of February 4, 1997
February 4, 1997
4(a)(16) Guarantee Agreement relating to HL&P's Form 8-K dated 1-3187 4.6-B
Capital Trust II dated as of February 4, 1997
February 4, 1997
4(a)(17) Form of Indenture governing 7% HI's Form 10-Q for the 1-7629 4
Automatic Common Exchange quarter ended June 30, 1997
Securities due July 1, 2000 between
the Company and the First National
Bank of Chicago, as Trustee
</TABLE>
157
<PAGE> 162
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
4(b)(1) Rights Agreement, dated July 11, HI's Form 8-K dated July 1-7629 4(a)(1)
1990, between the Company and Texas 11, 1990
Commerce Bank National Association,
as Rights Agent (Rights Agent),
which includes form of Statement of
Resolution Establishing Series of
Shares designated Series A
Preference Stock and form of Rights
Certificate
4(b)(2) Agreement and Appointment of Agent, HI's Form 8-K dated July 1-7629 4(a)(2)
dated as of July 11, 1990, between 11, 1990
the Company and the Rights Agent
4(b)(3) Form of Amended and Restated Rights Registration Statement on 333-11329 4(b)(1)
Agreement executed on August 6, Form S-4
1997, including form of Statement
of Resolution Establishing Series
Shares Designated Series A
Preference Stock and form of
Rights Agreement
4(c) Indenture, dated as of April 1, HI's Form 10-Q for the 1-7629 4(b)
1991, between the Company and
quarter ended June 30, 1991
NationsBank of Texas, National
Association, as Trustee
4(d)(1) Credit Agreement, dated as of HI's Form 10-Q for the 1-7629 10(f)
August 6, 1997, by and among quarter ended June 30, 1997
Houston Industries FinanceCo
LP, HI, Chase Manhattan Bank
and the other banks named therein
4(d)(2) First Amendment to Exhibit 4(d)(1) Form 10-K for the year 1-3187 4(d)(1)
dated as of December 27, 1997 ended December 31, 1997
4(d)(3) Second Amendment to Exhibit 4(d)(1) Form 10-K for the year 1-3187 4(d)(2)
dated as of February 27, 1998 ended December 31, 1997
+4(d)(4) Third Amendment to Exhibit 4(d)(1)
dated as of November 9 , 1998
</TABLE>
158
<PAGE> 163
Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, the Company has not
filed as exhibits to this Form 10-K certain long-term debt instruments,
including indentures, under which the total amount of securities authorized do
not exceed 10 percent of the total assets of the Company and its subsidiaries
on a consolidated basis. The Company hereby agrees to furnish a copy of any
such instrument to the SEC upon request.
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(a) Executive Benefit Plan of the HI's Form 10-Q for the 1-7629 10(a)(1),
Company and First and Second quarter ended March 31, 1987 10(a)(2),
Amendments thereto effective as of and
June 1, 1982, July 1, 1984, and 10(a)(3)
May 7, 1986, respectively
*10(b)(1) Executive Incentive Compensation HI's Form 10-K for the year 1-7629 10(b)
Plan of the Company effective as ended December 31, 1991
of January 1, 1982
*10(b)(2) First Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(a)
10(b)(1) effective as of March 30, quarter ended March 31, 1992
1992
*10(b)(3) Second Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(b)
10(b)(1) effective as of November ended December 31, 1992
4, 1992
*10(b)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(b)(4)
10(b)(1) effective as of ended December 31, 1994
September 7, 1994
*10(b)(5) Fourth Amendment to Exhibit Form 10-K for the year 1-3187 10(b)(5)
10(b)(1) effective as of August 6, ended December 31, 1997
1997
*10(c)(1) Executive Incentive Compensation HI's Form 10-Q for the 1-7629 10(b)(1)
Plan of the Company effective as quarter ended March 31, 1987
of January 1, 1985
*10(c)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(b)(3)
10(c)(1) effective as of January ended December 31, 1988
1, 1985
*10(c)(3) Second Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(c)(3)
10(c)(1) effective as of January ended December 31, 1991
1, 1985
*10(c)(4) Third Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(b)
10(c)(1) effective as of March 30, quarter ended March 31, 1992
1992
*10(c)(5) Fourth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(c)(5)
10(c)(1) effective as of November ended December 31, 1992
4, 1992
</TABLE>
159
<PAGE> 164
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(c)(6) Fifth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(c)(6)
10(c)(1) effective as of September ended December 31, 1994
7, 1994
*10(c)(7) Sixth Amendment to Exhibit Form 10-K for the year 1-3187 10(c)(7)
10(c)(1) effective as of August 6, ended December 31, 1997
1997
*10(d) Executive Incentive Compensation HI's Form 10-Q for the 1-7629 10(b)(2)
Plan of Houston Lighting & Power quarter ended March 31, 1987
Company effective as of January 1,
1985
*10(e)(1) Executive Incentive Compensation HI's Form 10-Q for the 1-7629 10(b)
Plan of the Company effective as quarter ended June 30, 1989
of January 1, 1989
*10(e)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(e)(2)
10(e)(1) effective as of January ended December 31, 1991
1, 1989
*10(e)(3) Second Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(c)
10(e)(1) effective as of March 30, quarter ended March 31, 1992
1992
*10(e)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(c)(4)
10(e)(1) effective as of November ended December 31, 1992
4, 1992
*10(e)(5) Fourth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(e)(5)
10(e)(1) effective as of September ended December 31, 1994
7, 1994
*10(f)(1) Executive Incentive Compensation HI's Form 10-K for the year 1-7629 10(b)
Plan of the Company effective as ended December 31, 1990
of January 1, 1991
*10(f)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(f)(2)
10(f)(1) effective as of January ended December 31, 1991
1, 1991
*10(f)(3) Second Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(d)
10(f)(1) effective as of March 30, quarter ended March 31, 1992
1992
*10(f)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(f)(4)
10(f)(1) effective as of November ended December 31, 1992
4, 1992
</TABLE>
160
<PAGE> 165
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(f)(5) Fourth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(f)(5)
10(f)(1) effective as of January ended December 31, 1992
1, 1993
*10(f)(6) Fifth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(f)(6)
10(f)(1) effective in part, ended December 31, 1994
January 1, 1995, and in part,
September 7, 1994
*10(f)(7) Sixth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(a)
10(f)(1) effective as of August 1, quarter ended June 30, 1995
1995
*10(f)(8) Seventh Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(a)
10(f)(1) effective as of January quarter ended June 30, 1996
1, 1996
*10(f)(9) Eighth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(a)
10(f)(1) effective as of January quarter ended June 30, 1997
1, 1997
*10(f)(10) Ninth Amendment to Exhibit Form 10-K for the year 1-3187 10(f)(10)
10(f)(1) effective in part, ended December 31, 1997
January 1, 1997, and in part,
January 1, 1998
*10(g) Benefit Restoration Plan of the HI's Form 10-Q for the 1-7629 10(c)
Company, effective as of June 1, quarter ended March 31, 1987
1985
*10(h) Benefit Restoration Plan of the HI's Form 10-K for the year 1-7629 10(g)(2)
Company as amended and restated ended December 31, 1991
effective as of January 1, 1988
*10(i)(1) Benefit Restoration Plan of the HI's Form 10-K for the year 1-7629 10(g)(3)
Company, as amended and restated ended December 31, 1991
effective as of July 1, 1991
*10(i)(2) First Amendment to Exhibit Form 10-K for the year 1-3187 10(i)(2)
10(i)(1) effective in part, August ended December 31, 1997
6, 1997, in part, September 3, 1997, and in part, October 1,
1997
*10(j)(1) Deferred Compensation Plan of the HI's Form 10-Q for the 1-7629 10(d)
Company effective as of September quarter ended March 31, 1987
1, 1985
</TABLE>
161
<PAGE> 166
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(j)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(d)(2)
10(j)(1) effective as of September ended December 31, 1990
1, 1985
*10(j)(3) Second Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(e)
10(j)(1) effective as of March 30, quarter ended March 31, 1992
1992
*10(j)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(h)(4)
10(j)(1) effective as of June 2, ended December 31, 1993
1993
*10(j)(5) Fourth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(h)(5)
10(j)(1) effective as of September ended December 31, 1994
7, 1994
*10(j)(6) Fifth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(d)
10(j)(1) effective as of August 1, quarter ended June 30, 1995
1995
*10(j)(7) Sixth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(b)
10(j)(1) effective as of December quarter ended June 30, 1995
1, 1995
*10(j)(8) Seventh Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(b)
10(j)(1) effective as of January quarter ended June 30, 1997
1, 1997
*10(j)(9) Eighth Amendment to Exhibit Form 10-K for the year 1-3187 10(j)(9)
10(j)(1) effective as of September ended December 31, 1997
1, 1997
*10(j)(10) Ninth Amendment to Exhibit Form 10-K for the year 1-3187 10(j)(10)
10(j)(1) effective as of September ended December 31, 1997
3, 1997
*10(k)(1) Deferred Compensation Plan of the HI's Form 10-Q for the 1-7629 10(a)
Company effective as of January 1, quarter ended June 30, 1989
1989
*10(k)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(e)(3)
10(k)(1) effective as of January ended December 31, 1989
1, 1989
*10(k)(3) Second Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(f)
10(k)(1) effective as of March 30, quarter ended March 31, 1992
1992
</TABLE>
162
<PAGE> 167
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(k)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(i)(4)
10(k)(1) effective as of June 2, ended December 31, 1993
1993
*10(k)(5) Fourth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(i)(5)
10(k)(1) effective as of September ended December 31, 1994
7, 1994
*10(k)(6) Fifth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(c)
10(k)(1) effective as of August 1, quarter ended June 30, 1995
1995
*10(k)(7) Sixth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(c)
10(k)(1) effective December 1, 1995 quarter ended June 30, 1995
*10(k)(8) Seventh Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(c)
10(k)(1) effective as of January quarter ended June 30, 1997
1, 1997
*10(k)(9) Eighth Amendment to Exhibit Form 10-K for the year 1-3187 10(k)(9)
10(k)(1) effective in part October ended December 31, 1997
1, 1997 and in part January 1, 1998
*10(k)(10) Ninth Amendment to Exhibit Form 10-K for the year 1-3187 10(k)(10)
10(k)(1) effective as of September ended December 31, 1997
3, 1997
*10(l)(1) Deferred Compensation Plan of the HI's Form 10-K for the year 1-7629 10(d)(3)
Company effective as of January 1, ended December 31, 1990
1991
*10(l)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(j)(2)
10(l)(1) effective as of January ended December 31, 1991
1, 1991
*10(l)(3) Second Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(g)
10(l)(1) effective as of March 30, quarter ended March 31, 1992
1992
*10(l)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(j)(4)
10(l)(1) effective as of June 2, ended December 31, 1993
1993
*10(l)(5) Fourth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(j)(5)
10(l)(1) effective as of December ended December 31, 1993
1, 1993
</TABLE>
163
<PAGE> 168
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(l)(6) Fifth Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(j)(6)
10(l)(1) effective as of September ended December 31, 1994
7, 1994
*10(l)(7) Sixth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(b)
10(l)(1) effective as of August 1, quarter ended June 30, 1995
1995
*10(l)(8) Seventh Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(d)
10(l)(1) effective as of December quarter ended June 30, 1996
1, 1995
*10(l)(9) Eighth Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(d)
10(l)(1) effective as of January quarter ended June 30, 1997
1, 1997
*10(l)(10) Ninth Amendment to Exhibit Form 10-K for the year 1-3187 10(l)(10)
10(l)(1) effective in part August ended December 31, 1997
6, 1997, in part October 1, 1997, and in part January 1, 1998
*10(l)(11) Tenth Amendment to Exhibit Form 10-K for the year 1-3187 10(i)(11)
10(l)(1) effective as of September ended December 31, 1997
3, 1997
*10(m)(1) Long-Term Incentive Compensation HI's Form 10-Q for the 1-7629 10(c)
Plan of the Company effective as quarter ended June 30, 1989
of January 1, 1989
*10(m)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(f)(2)
10(m)(1) effective as of January ended December 31, 1989
1, 1990
*10(m)(3) Second Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(k)(3)
10(m)(1) effective as of December ended December 31, 1992
22, 1992
*10(m)(4) Third Amendment to Exhibit HI's Form 10-K for the year 1-3187 10(m)(4)
10(m)(1) effective as of August 6, ended December 31, 1997
1997
*10(n) Form of stock option agreement for HI's Form 10-Q for the 1-7629 10(h)
nonqualified stock options granted quarter ended March 31, 1992
under the Company's 1989 Long-Term
Incentive Compensation Plan
</TABLE>
164
<PAGE> 169
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(o) Forms of restricted stock HI's Form 10-Q for the 1-7629 10(i)
agreement for restricted stock quarter ended March 31, 1992
granted under the Company's 1989
Long-Term Incentive Compensation
Plan
*10(p)(1) 1994 Long-Term Incentive HI's Form 10-K for the year 1-7629 10(n)(1)
Compensation Plan of the Company ended December 31, 1993
effective as of January 1, 1994
*10(p)(2) Form of stock option agreement for HI's Form 10-K for the year 1-7629 10(n)(2)
non-qualified stock options ended December 31, 1993
granted under the Company's 1994
Long-Term Incentive Compensation
Plan
*10(p)(3) First Amendment to Exhibit HI's Form 10-Q for the 1-7629 10(e)
10(p)(1) effective as of May 9, quarter ended June 30, 1997
1997
*10(p)(4) Second Amendment to Exhibit Form 10-K for the year 1-3187 10(p)(4)
10(p)(1) effective as of August 6, ended December 31, 1997
1997
+*10(p)(5) Third Amendment to Exhibit
10(p)(1) effective as of January
1, 1998
*10(q)(1) Savings Restoration Plan of the HI's Form 10-K for the year 1-7629 10(f)
Company effective as of January 1, ended December 31, 1990
1991
*10(q)(2) First Amendment to Exhibit HI's Form 10-K for the year 1-7629 10(l)(2)
10(q)(1) effective as of January ended December 31, 1991
1, 1992
*10(q)(3) Second Amendment to Exhibit Form 10-K for the year 1-3187 10(q)(3)
10(q)(1) effective in part, August ended December 31, 1997
6, 1997, and in part, October 1,
1997
*10(r)(1) Director Benefits Plan, effective HI's Form 10-K for the year 1-7629 10(m)
as of January 1, 1992 ended December 31, 1991
+*10(r)(2) First Amendment to Exhibit
10(r)(1) effective as of August 6,
1997
</TABLE>
165
<PAGE> 170
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(s)(1) Executive Life Insurance Plan of HI's Form 10-K for the year 1-7629 10(q)
the Company effective as of ended December 31, 1993
January 1, 1994
*10(s)(2) First Amendment to Exhibit HI's Form 10-Q for the 1-7629 10
10(s)(1) effective as of January quarter ended June 30, 1995
1, 1994
*10(s)(3) Second Amendment to Exhibit Form 10-K for the year 1-3187 10(s)(3)
10(s)(1) effective as of August 6, ended December 31, 1997
1997
*10(t) Employment and Supplemental HI's Form 10-Q for the 1-7629 10(f)
Benefits Agreement between HL&P quarter ended March 31, 1987
and Hugh Rice Kelly
10(u)(1) Houston Industries Incorporated HI's Form 10-K for the year 1-7629 10(s)(4)
Savings Trust between the Company ended December 31, 1995
and The Northern Trust Company, as
Trustee (as amended and restated
effective July 1, 1995)
10(u)(2) Note Purchase Agreement between HI's Form 10-K for the year 1-7629 10(j)(3)
the Company and the ESOP Trustee, ended December 31, 1990
dated as of October 5, 1990
10(v)(1) Stockholder's Agreement dated as Schedule 13-D dated July 6, 5-19351 2
of July 6, 1995 between the 1995
Company and Time Warner Inc.
10(v)(2) Registration Rights Agreement Schedule 13-D dated July 6, 5-19351 3
dated as of July 6, 1995 between 1995
the Company and Time Warner Inc.
10(v)(3) Amendment to Exhibits 10(v)(1) and HI's Form 10-K for the year 1-7629 10(x)(4)
10(v)(2) dated November 18, 1996 ended December 31, 1996
10(v)(4) Certificate of Voting Powers, Schedule 13-D dated July 6, 5-19351 4
Designations, Preferences and 1995
Relative Participating, Optional
or Other Special Rights, and
Qualifications, Limitations or
Restrictions Thereof of Series D
Convertible Preferred Stock of
Time Warner Inc.
</TABLE>
166
<PAGE> 171
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
*10(w)(1) Houston Industries Incorporated HI's Form 10-K for the year 1-7629 10(7)
Executive Deferred Compensation ended December 31, 1995
Trust, effective as of December
19, 1995
*10(w)(2) First Amendment to Exhibit Form 10-Q for the quarter 1-3187 10
10(w)(1) effective as of August 6, ended June 30, 1998
1997
*10(x) Supplemental Pension Agreement, Registration Statement on 333-11329 10(aa)
dated July 17, 1996, between the Form S-4
Company and Lee W. Hogan
*10(y) Consulting Agreement, dated HI's Form 10-K for the year 1-7629 10(bb)
January 14, 1997, between the ended December 31, 1996
Company and Milton Carroll
*10(z)(1) Employment Agreement, dated HI's Form 10-K for the year 1-7629 10(cc)
February 25, 1997, between the ended December 31, 1996
Company and Don D. Jordan
10(z)(2) Amended and Restated Employment Form 10-K for the year 1-3187 10(z)(2)
Agreement, dated November 7, 1997, ended December 31, 1997
between the Company and Don D.
Jordan
*10(aa)(1) Executive Severance Benefits Plan Form 10-K for the year 1-3187 10(aa)(1)
of the Company and Summary Plan ended December 31, 1997
Description effective as of
September 3, 1997
*10(aa)(2) Form of Severance Agreements Form 10-K for the year 1-3187 10(aa)(2)
between the Company and each of ended December 31, 1997
the following executive officers:
Lee W. Hogan, Hugh Rice Kelly, R.
Steve Letbetter, and Stephen W.
Naeve
+*10(aa)(3) Form of Severance Agreements,
between the Company and each of
the following executive officers:
David M. McClanahan, Charles M.
Oglesby, Joe Bob Perkins, and Mary
P. Ricciardello
</TABLE>
167
<PAGE> 172
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- --------------- ------------------------------------ ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
+*10(bb) Employment Agreement, dated as of
February 16, 1998, between the
Company and Charles M. Oglesby,
and Waiver and Release pertaining
thereto
+*10 (c)(c) Fifth Amendment to the Houston
Industries Incorporated Savings
Plan effective as of October 15,
1997
+*10 (d)(d) Fourth Amendment to the Houston
Industries Energy, Inc. Long-Term
Project Incentive Compensation
Plan, effective as of January 1,
1997
+*10 (e)(e) First Amendment to the Houston
Industries Incorporated Stock Plan
for Outside Directors, effective
as of August 6, 1997
+12 Computation of Ratios of Earnings
to Fixed Charges
+21 Subsidiaries of the Company
+23 Consent of Deloitte & Touche LLP
+27 Financial Data Schedule
+99(a) Letter, dated February 2, 1999,
from Secretary of State of the
State of Texas regarding Assumed
Name filed by Houston Industries
Incorporated to conduct business
under the name Reliant Energy,
Incorporated
</TABLE>
168
<PAGE> 173
(B) RELIANT ENERGY RESOURCES CORP.
<TABLE>
<CAPTION>
SEC FILE OR
EXHIBIT REPORT OR REGISTRATION EXHIBIT
NUMBER DESCRIPTION REGISTRATION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
2(a)(1) Agreement and Plan of Merger among HI's Form 8-K dated August 1-7629 2
the Company, HL&P, HI Merger, Inc. 11, 1996
and NorAm dated August 11, 1996
2(a)(2) Amendment to Agreement and Plan of Registration Statement on 333-11329 2(c)
Merger among the Company, HL&P, HI Form S-4
Merger, Inc. and NorAm dated August
11, 1996
3(a)(1) Certificate of Incorporation of Form 10-K for the year 1-3187 3(a)(1)
Resources ended December 31, 1997
3(a)(2) Certificate of Merger merging Form 10-K for the year 1-3187 3(a)(2)
former NorAm Energy Corp. with and ended December 31, 1997
into HI Merger, Inc. dated August
6, 1997
+3(a)(3) Certificate of Amendment changing
the name to Reliant Energy
Resources Corp.
3(b) Bylaws of Resources Form 10-K for the year 1-3187 3(b)
ended December 31, 1997
4(a)(1) Indenture, dated as of December 1, NorAm's Form 10-K for the 1-13265 4.14
1986, between NorAm and Citibank, year ended December 31, 1986
N.A., as Trustee
4(a)(2) First Supplemental Indenture to Form 10-K for the year 1-3187 4(a)(2)
Exhibit 4(a)(1) dated as of ended December 31, 1997
September 30, 1988
4(a)(3) Second Supplemental Indenture to Form 10-K for the year 1-3187 4(a)(3)
Exhibit 4(a)(1) dated as of ended December 31, 1997
November 15, 1989
4(a)(4) Third Supplemental Indenture to Form 10-K for the year 1-3187 4(a)(4)
Exhibit 4(a)(1) dated as of August ended December 31, 1997
6, 1997
4(b)(1) Indenture, dated as of March 31, NorAm's Registration 33-14586 4.20
1987, between NorAm and Chase Statement on Form S-3
Manhattan Bank, N.A., as Trustee,
authorizing 6% Convertible
Subordinated Debentures due 2012
</TABLE>
169
<PAGE> 174
<TABLE>
<CAPTION>
SEC FILE OR
EXHIBIT REPORT OR REGISTRATION EXHIBIT
NUMBER DESCRIPTION REGISTRATION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
4(b)(2) Supplemental Indenture to Exhibit Form 10-K for the year 1-3187 4(b)(2)
4(b)(1) dated as of August 6, 1997 ended December 31, 1997
4(c)(1) Indenture, dated as of April 15, NorAm's Registration 33-23375 4.1
1990, between NorAm and Citibank, Statement on Form S-3
N.A., as Trustee
4(c)(2) Supplemental Indenture to Exhibit Form 10-K for the year 1-3187 4(c)(2)
4(c)(1) dated as of August 6, 1997 ended December 31, 1997
4(d)(1) Form of Indenture between NorAm and NorAm's Registration 33-64001 4.8
The Bank of New York as Trustee Statement on Form S-3
4(d)(2) Form of First Supplemental NorAm's Form 8-K dated June 1-13265 4.01
Indenture to Exhibit 4(d)(1) 10, 1996
4(d)(3) Second Supplemental Indenture to Form 10-K for the year 1-3187 4(d)(3)
Exhibit 4(d)(1) dated as of August ended December 31, 1997
6, 1997
4(e) Indenture, dated as of December 1, Registration Statement on 333-41017 4.1
1997, between Resources and Chase Form S-3
Bank of Texas, National Association
4(f)(1) Indenture, dated as of February 1, Form 8-K dated February 5, 1-13265 4.1
1998, between the Company and Chase 1998
Bank of Texas, National
Association, as Trustee
4(f)(2) Supplemental Indenture No. 1, dated Form 8-K dated February 5, 1-13265 4.2
as of February 1, 1998, providing 1998
for the issuance of the Company's 6
1/2% Debentures due February 1, 2008
</TABLE>
There have not been filed as exhibits to this Form 10-K certain long-term
debt instruments, including indentures, under which the total amount of
securities do not exceed 10 percent of the total assets of Resources. Resources
hereby agrees to furnish a copy of any such instrument to the SEC upon request.
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
10(a) Service Agreement by and between NorAm's Form 10-K for the 1-13265 10.20
Mississippi River Transmission year ended December 31, 1989
Corporation and Laclede Gas Company
dated August 22, 1989
+12 Computation of Ratios of Earnings
to Fixed Charges
</TABLE>
170
<PAGE> 175
<TABLE>
<CAPTION>
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ------------------------------------- ----------------------------- ---------------- ----------------
<S> <C> <C> <C> <C>
+27 Financial Data Schedule
</TABLE>
171
<PAGE> 1
[REI -- EXHIBIT 4(d)(4)]
THIRD AMENDMENT TO CREDIT AGREEMENT
THIS THIRD AMENDMENT, dated as of November 9, 1998 (this
"Amendment"), to the Credit Agreement dated as of August 6, 1997 (as amended by
the First Amendment to the Credit Agreement dated as of December 23, 1997 and
the Second Amendment to the Credit Agreement dated as of February 27, 1998 (the
"Second Amendment") and as the same may be amended, supplemented or otherwise
modified from time to time, the "Credit Agreement"), is made and entered into
among: (i) HOUSTON INDUSTRIES FINANCECO LP, a Delaware limited partnership (the
"Borrower"); (ii) HOUSTON INDUSTRIES INCORPORATED, a Texas corporation ("HII");
(iii) the several banks and other financial institutions from time to time
parties thereto (collectively, the "Banks," and each individually; a "Bank");
(iv) CHASE SECURITIES INC., as Arranger (in such capacity, the "Arranger"); and
(v) THE CHASE MANHATTAN BANK, as Administrative Agent (in such capacity, the
"Agent").
W I T N E S S E T H:
WHEREAS, pursuant to the Credit Agreement, the Banks have
agreed to make certain loans and other extensions of credit to the Borrower; and
WHEREAS, the Borrower has requested that the Credit Agreement
be amended to, among other things, modify the negative covenant relating to the
ratio of HII's Consolidated Indebtedness for Borrowed Money to Consolidated
Capitalization;
NOW, THEREFORE, in consideration of the premises and of the
mutual agreements, representations and warranties herein set forth, and for
other good and valuable consideration, the receipt and adequacy of which is
hereby acknowledged, the parties hereto hereby agree as follows:
SECTION 1. DEFINITIONS.
1.1 Defined Terms. Unless otherwise defined herein and except
as set forth in this Amendment, terms defined in the Credit Agreement are used
herein as therein defined.
SECTION 2. AMENDMENTS TO THE CREDIT AGREEMENT.
2.1 Amendment to Section 1.1 of the Credit Agreement. Section
1.1 of the Credit Agreement is hereby amended by deleting from the definition of
"Security Documents" the words ", the Pledge and Collateral Agency Agreement"
(the Pledge And Collateral Agency Agreement having been terminated pursuant to
the Second Amendment).
1
<PAGE> 2
2.2 Amendment to Section 8.4(b) of the Credit Agreement.
Section 8.4(b) of the Credit Agreement is hereby amended to read in its entirety
as follows:
"(b) Financial Ratios. HII will not permit
the ratio of Consolidated Indebtedness for Borrowed Money to
Consolidated Capitalization to exceed 0.65:1.00."
2.3 Amendment to Section 8.4.(g)(i) of the Credit Agreement.
Section 8.4(g)(i) of the Credit Agreement is hereby amended by reinserting the
phrase "of HII so long as the source of payment therefor is received by such
Subsidiary" in the ninth line thereof immediately following the phrase "advances
or Guarantees made by any Subsidiary" (it being understood that such reinserted
text was inadvertently omitted in the Second Amendment), so that such Section
shall read in its entirety as follows:
"(i) at any time (x) at which no Default or Event of
Default has occurred and is continuing, (y) that Projected Available
Cash exceeds Projected Borrower Debt Service for the fiscal quarter of
HII then in effect and (z) that the long-term senior secured debt
rating in effect for HII is at least BBB by S&P or Baa2 by Moody's, HII
shall be permitted to make direct or indirect HII Investments in
Subsidiaries of HII, and HII Investments constituting purchases or
acquisitions of assets, securities or Capital Stock that result, upon
consummation thereof, in such assets, securities or Capital Stock being
owned by or becoming Subsidiaries of HII (it being understood that the
foregoing shall not apply to any investments, acquisitions, loans,
advances or Guarantees made by any Subsidiary of HII so long as the
source of payment therefor is received by such Subsidiary in accordance
with this clause (i) and the other applicable provisions of this
Agreement); provided that the requirements set forth in clauses (x) and
(y) above would be satisfied after giving effect to (1) such HII
Investments and (2) any sources of cash available or reasonably
expected by HII at the time of the proposed investment to be available
during the fiscal quarter of HII then in effect;"
SECTION 3. MISCELLANEOUS.
3.1 Effectiveness and References. This Amendment shall become
effective on the date upon which the Agent shall have received counterparts of
this Amendment, duly executed and delivered by the Borrower, HII, the Agent and
the Majority Banks. On and after said effective date, the term "Agreement" as
used in the Credit Agreement, the other loan documents executed in connection
therewith, and any other instrument, document, or writing furnished to the
Banks, the Agent, or the Arranger by the Borrower shall mean the Credit
Agreement, as amended hereby.
3.2 Representations and Warranties. After giving effect to the
amendments contained herein, each of the Borrower and HII hereby confirm,
reaffirm and restate the representations and warranties set forth in Article VII
of the Credit Agreement; provided that each reference in such Article VII to
"this Agreement" shall be deemed to be a reference both to this Amendment and to
the Credit Agreement as previously amended and as amended by this Amendment. On
the date hereof, no Default or Event of Default has occurred or is continuing.
2
<PAGE> 3
3.3 Payment of Expenses. The Borrower agrees to pay or
reimburse the Agent for all of its out-of-pocket costs and reasonable expenses
incurred in connection with this Amendment, any other documents prepared in
connection herewith and the transactions contemplated hereby, including, without
limitation, the reasonable fees and disbursements of counsel to the Agent.
3.4 Continuing Effect; No Other Amendments. Except as
expressly amended hereby, all of the terms and provisions of the Credit
Agreement and the other Loan Documents (as may have been previously amended) are
and shall remain in full force and effect. The amendments contained herein shall
not constitute an amendment or waiver of any other provision of the Credit
Agreement or the other Loan Documents except as expressly set forth herein.
3.5 Counterparts. This Amendment may be executed in any number
of counterparts by the parties hereto, each of which counterparts when so
executed shall be an original, but all the counterparts shall together
constitute one and the same instrument.
3.6 GOVERNING LAW. THIS AMENDMENT SHALL BE GOVERNED
BY, AND CONSTRUED AND INTERPRETED IN ACCORDANCE WITH, THE LAWS OF
THE STATE OF NEW YORK.
IN WITNESS WHEREOF, the parties hereto have caused this
Amendment to be executed and delivered by their respective duly authorized
officers as of the date first above written.
HOUSTON INDUSTRIES
FINANCECO LP
By: HOUSTON INDUSTRIES
FINANCECO GP, LLC,
its General Partner
By:
-----------------------------------
Title:
--------------------------------
HOUSTON INDUSTRIES INCORPORATED
By:
-----------------------------------
Title:
--------------------------------
3
<PAGE> 4
THE CHASE MANHATTAN BANK, as
Agent and as a Bank
By:
-----------------------------------
Title:
--------------------------------
BANKBOSTON, N.A.
By:
-----------------------------------
Title:
--------------------------------
BANK OF MONTREAL
By:
-----------------------------------
Title:
--------------------------------
THE BANK OF NEW YORK
By:
-----------------------------------
Title:
--------------------------------
THE BANK OF NOVA SCOTIA
By:
-----------------------------------
Title:
--------------------------------
THE BANK OF TOKYO-MITSUBISHI
LTD., HOUSTON AGENCY
By:
-----------------------------------
Title:
--------------------------------
4
<PAGE> 5
BARCLAYS BANK PLC
By:
-----------------------------------
Title:
--------------------------------
CREDIT AGRICOLE INDOSUEZ
By:
-----------------------------------
Title:
--------------------------------
By:
-----------------------------------
Title:
--------------------------------
CIBC INC.
By:
-----------------------------------
Title:
--------------------------------
CITIBANK, N.A.
By:
-----------------------------------
Title:
--------------------------------
COMERICA BANK
By:
-----------------------------------
Title:
--------------------------------
5
<PAGE> 6
COMMERZBANK
AKTIENGESELLSCHAFT,
ATLANTA AGENCY
By:
-----------------------------------
Title:
--------------------------------
By:
-----------------------------------
Title:
--------------------------------
CREDIT LYONNAIS
NEW YORK BRANCH
By:
-----------------------------------
Title:
--------------------------------
CREDIT SUISSE FIRST BOSTON
By:
-----------------------------------
Title:
--------------------------------
By:
-----------------------------------
Title:
--------------------------------
THE DAI-ICHI KANGYO BANK,
LIMITED
By:
-----------------------------------
Title:
--------------------------------
FIRST UNION NATIONAL BANK
By:
-----------------------------------
Title:
--------------------------------
6
<PAGE> 7
FLEET NATIONAL BANK
By:
-----------------------------------
Title:
--------------------------------
THE FUJI BANK, LIMITED -
HOUSTON AGENCY
By:
-----------------------------------
Title:
--------------------------------
THE INDUSTRIAL BANK OF JAPAN,
LIMITED, NEW YORK BRANCH
By:
-----------------------------------
Title:
--------------------------------
THE LONG-TERM CREDIT BANK OF
JAPAN, LTD.
By:
-----------------------------------
Title:
--------------------------------
MELLON BANK, N.A.
By:
-----------------------------------
Title:
--------------------------------
MORGAN GUARANTY TRUST
COMPANY OF NEW YORK
By:
-----------------------------------
Title:
--------------------------------
7
<PAGE> 8
NATIONSBANK, N.A. (SUCCESSOR BY
MERGER TO NATIONSBANK OF TEXAS, N.A.)
By:
-----------------------------------
Title:
--------------------------------
THE NORTHERN TRUST COMPANY
By:
-----------------------------------
Title:
--------------------------------
ROYAL BANK OF CANADA
By:
-----------------------------------
Title:
--------------------------------
THE SAKURA BANK, LIMITED
By:
-----------------------------------
Title:
--------------------------------
SOCIETE GENERALE,
SOUTHWEST AGENCY
By:
-----------------------------------
Title:
--------------------------------
THE SUMITOMO BANK, LIMITED
By:
-----------------------------------
Title:
--------------------------------
8
<PAGE> 9
THE TOKAI BANK, LTD.
By:
-----------------------------------
Title:
--------------------------------
TORONTO DOMINION (TEXAS), INC.
By:
-----------------------------------
Title:
--------------------------------
UBS AG, NEW YORK BRANCH
By:
-----------------------------------
Title:
--------------------------------
By:
-----------------------------------
Title:
--------------------------------
WACHOVIA BANK OF GEORGIA, N.A.
By:
-----------------------------------
Title:
--------------------------------
WESTDEUTSCHE LANDESBANK
GIROZENTRALE, NEW YORK
BRANCH
By:
-----------------------------------
Title:
--------------------------------
By:
-----------------------------------
Title:
9
<PAGE> 10
THE YASUDA TRUST AND BANKING
COMPANY LIMITED
NEW YORK BRANCH
By:
-----------------------------------
Title:
--------------------------------
10
<PAGE> 1
[REI -- EXHIBIT 10(p)(5)]
1994 HOUSTON INDUSTRIES INCORPORATED
LONG-TERM INCENTIVE COMPENSATION PLAN
Third Amendment
Houston Industries Incorporated, a Texas corporation (the "Company"),
having established the 1994 Houston Industries Incorporated Long-Term Incentive
Compensation Plan, effective January 1, 1994, and as thereafter amended (the
"Plan"), and having reserved the right under Section 12.1 thereof to amend the
Plan, does hereby amend the Plan, effective as of January 1, 1998, subject to
the approval of the shareholders of the Company, as follows:
1. The first two sentences of Section 3.2 of the Plan are hereby
amended to read as follows:
"The aggregate number of shares of Common Stock which may be issued
under this Plan shall not exceed Eighteen Million (18,000,000) shares,
subject to adjustment as hereinafter provided. All or any part of such
Eighteen Million shares may be issued pursuant to Stock Awards."
2. The last sentence of Section 3.2 of the Plan is hereby amended in
its entirety to read as follows:
"Notwithstanding anything herein to the contrary, no Key Employee may be
granted, during any calendar year, (i) Options (including Stock
Appreciation Rights) covering, in the aggregate, more than 500,000 shares
of Common Stock authorized under the Plan or (ii) Restricted Stock Awards
(including 'opportunity shares') covering, in the aggregate, more than
50,000 shares of Common Stock authorized under the Plan, in each case
subject to adjustment in the same manner provided in Section 13.3."
-1-
<PAGE> 2
IN WITNESS WHEREOF, Houston Industries Incorporated has caused this
Amendment to be executed by its duly authorized officers, this 13th day of May,
1998, but effective as of January 1, 1998.
HOUSTON INDUSTRIES INCORPORATED
By /s/ R. STEVE LETBETTER
---------------------------------
ATTEST:
/s/ RICHARD B. DAUPHIN
- ----------------------------------
-2-
<PAGE> 1
[REI -- EXHIBIT 10(r)(2)]
HOUSTON INDUSTRIES INCORPORATED
DIRECTOR BENEFITS PLAN
(Effective January 1, 1992)
First Amendment
Houston Industries Incorporated, a Texas corporation (the "Company"),
having adopted the Houston Industries Incorporated Director Benefits Plan,
effective January 1, 1992 (the "Plan"), and having reserved the right under
Section 6.01 thereof to amend the Plan, does hereby amend the Plan, effective as
of August 6, 1997, to read as follows:
1. Section 4.01 of the Plan is hereby amended by adding the following
sentence to the end thereof:
"Full years of service completed while a director of NorAm Energy Corp.,
any predecessor thereto, or any division or subsidiary of NorAm Energy
Corp., or while a director of any 'advisory board' of NorAm Energy Corp. or
its subsidiaries or divisions, will be included in the calculation of full
years of service under the Plan."
2. New Section 4.04 is added to the Plan at the end of Article IV to
read as follows:
"4.04 Benefit Offset. Notwithstanding any provision hereto to the
contrary, the annual benefit amount payable to a Director calculated under
Section 4.01 hereof shall be reduced by the amount of any annual benefit
that the Director receives under the NorAm Energy Corp. Directors'
Retirement Plan."
-1-
<PAGE> 2
IN WITNESS WHEREOF, Houston Industries Incorporated has caused this
Amendment to be executed by its duly authorized officers this 26th day of
February, 1998, but effective as of August 6, 1997.
HOUSTON INDUSTRIES INCORPORATED
By /s/ LEE W. HOGAN
--------------------------------------
Name: Lee W. Hogan
-------------------------------
Title: Executive Vice President
------------------------------
ATTEST:
/s/ RICHARD B. DAUPHIN
- -----------------------------------
-2-
<PAGE> 1
[REI -- EXHIBIT 10(aa)(3)]
FORM OF SEVERANCE AGREEMENT
THIS SEVERANCE AGREEMENT ("Agreement") is made and effective
as of the 3rd day of September, 1997, by and between HOUSTON INDUSTRIES
INCORPORATED, a Texas corporation having its principal place of business in
Houston, Harris County, Texas, and ___________________, an individual currently
residing in Harris County, Texas ("Executive"). All terms defined in Section 1
shall, throughout this Agreement, have the meanings given therein.
1. DEFINITIONS:
"AFFILIATE" means any company controlled by, controlling or
under common control with the Company within the meaning of Section 414 of the
Internal Revenue Code of 1986, as amended (the "Code").
"BOARD" means the board of directors of the Company.
"CAUSE" means Executive's (a) gross negligence in the
performance of Executive's duties, (b) intentional and continued failure to
perform Executive's duties, (c) intentional engagement in conduct which is
materially injurious to the Company or its Affiliates (monetarily or otherwise)
or (d) conviction of a felony or a misdemeanor involving moral turpitude. For
this purpose, an act or failure to act on the part of Executive will be deemed
"intentional" only if done or omitted to be done by Executive not in good faith
and without reasonable belief that his/her action or omission was in the best
interest of the Company, and no act or failure to act on the part of Executive
will be deemed "intentional" if it was due primarily to an error in judgment or
negligence.
"CHANGE IN EMPLOYMENT" shall mean any one or more of the
following:
(a) a significant reduction in the duties or
responsibilities of Executive from those applicable to him/her
immediately prior to the date on which a Change of Control occurs (or,
in the case of an Anticipatory Change in Employment, immediately prior
to the date of the Binding CIC Agreement);
(b) a reduction in Executive's total remuneration
(including salary, bonus, qualified retirement benefits, nonqualified
benefits, welfare benefits and any other employee benefits) from that
provided to Executive immediately prior to the date on which a Change
of Control occurs (or, in the case of an Anticipatory Change in
Employment, immediately prior to the date of the Binding CIC
Agreement); provided, however, that a contemporaneous diminution of or
reduction in qualified retirement benefits and/or welfare benefits
which is of general application and which uniformly and
contemporaneously reduces or diminishes the benefits of all covered
employees by the same percentage shall be ignored and not be
considered a reduction in total remuneration for purposes of this
paragraph (b);
<PAGE> 2
(c) a change in the location of Executive's principal
place of employment with the Company by more than 35 miles from the
location where Executive was principally employed immediately prior to
the date on which a Change of Control occurs (or, in the case of an
Anticipatory Change in Employment, immediately prior to the date of
the Binding CIC Agreement); or
(d) a failure by the Company to provide directors and
officers liability insurance covering Executive comparable to that
provided to Executive immediately prior to the date on which a Change
of Control occurs (or, in the case of an Anticipatory Change in
Employment, immediately prior to the date of the Binding CIC
Agreement).
A "CHANGE OF CONTROL" or "CIC" shall be deemed to have
occurred upon the occurrence of any of the following events:
(a) 30% OWNERSHIP CHANGE: Any Person makes an
acquisition of Outstanding Voting Stock and is, immediately
thereafter, the beneficial owner of 30% or more of the then
Outstanding Voting Stock, unless such acquisition is made directly
from the Company in a transaction approved by a majority of the
Incumbent Directors; or any group is formed that is the beneficial
owner of 30% or more of the Outstanding Voting Stock; or
(b) BOARD MAJORITY CHANGE: Individuals who are Incumbent
Directors cease for any reason to constitute a majority of the members
of the Board; or
(c) MAJOR MERGERS AND ACQUISITIONS: Consummation of a
Business Combination unless, immediately following such Business
Combination, (i) all or substantially all of the individuals and
entities that were the beneficial owners of the Outstanding Voting
Stock immediately prior to such Business Combination beneficially own,
directly or indirectly, more than 70% of the then outstanding shares
of voting stock of the parent corporation resulting from such Business
Combination in substantially the same relative proportions as their
ownership, immediately prior to such Business Combination, of the
Outstanding Voting Stock, (ii) if the Business Combination involves
the issuance or payment by the Company of consideration to another
entity or its shareholders, the total fair market value of such
consideration plus the principal amount of the consolidated long-term
debt of the entity or business being acquired (in each case,
determined as of the date of consummation of such Business Combination
by a majority of the Incumbent Directors) does not exceed 50% of the
sum of the fair market value of the Outstanding Voting Stock plus the
principal amount of the Company's consolidated long-term debt (in each
case, determined immediately prior to such consummation by a majority
of the Incumbent Directors), (iii) no Person (other than any
corporation resulting from such Business Combination) beneficially
owns, directly or indirectly, 30% or more of the then outstanding
shares of voting stock of the parent corporation resulting from such
Business Combination and (iv) a majority of the members of the board
of directors of the parent corporation resulting from such Business
Combination were Incumbent
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Directors of the Company immediately prior to consummation of such
Business Combination; or
(d) MAJOR ASSET DISPOSITIONS: Consummation of a Major
Asset Disposition unless, immediately following such Major Asset
Disposition, (i) individuals and entities that were beneficial owners
of the Outstanding Voting Stock immediately prior to such Major Asset
Disposition beneficially own, directly or indirectly, more than 70% of
the then outstanding shares of voting stock of the Company (if it
continues to exist) and of the entity that acquires the largest
portion of such assets (or the entity, if any, that owns a majority of
the outstanding voting stock of such acquiring entity) and (ii) a
majority of the members of the board of directors of the Company (if
it continues to exist) and of the entity that acquires the largest
portion of such assets (or the entity, if any, that owns a majority of
the outstanding voting stock of such acquiring entity) were Incumbent
Directors of the Company immediately prior to consummation of such
Major Asset Disposition.
For purposes of the foregoing,
(1) the term "Person" means an individual, entity or
group;
(2) the term "group" is used as it is defined for
purposes of Section 13(d)(3) of the Securities Exchange Act of 1934
(the "Exchange Act");
(3) the term "beneficial owner" is used as it is defined
for purposes of Rule 13d-3 under the Exchange Act;
(4) the term "Outstanding Voting Stock" means outstanding
voting securities of the Company entitled to vote generally in the
election of directors; and any specified percentage or portion of the
Outstanding Voting Stock (or of other voting stock) shall be
determined based on the combined voting power of such securities;
(5) the term "Incumbent Director" means a director of the
Company (x) who was a director of the Company on September 1, 1997 or
(y) who becomes a director subsequent to such date and whose election,
or nomination for election by the Company's shareholders, was approved
by a vote of a majority of the Incumbent Directors at the time of such
election or nomination, except that any such director shall not be
deemed an Incumbent Director if his or her initial assumption of
office occurs as a result of an actual or threatened election contest
or other actual or threatened solicitation of proxies by or on behalf
of a Person other than the Board;
(6) the term "election contest" is used as it is defined
for purposes of Rule 14a-11 under the Exchange Act;
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<PAGE> 4
(7) the term "Business Combination" means (x) a merger or
consolidation involving the Company or its stock or (y) an acquisition
by the Company, directly or through one or more subsidiaries, of
another entity or its stock or assets;
(8) the term "parent corporation resulting from a
Business Combination" means the Company if its stock is not acquired
or converted in the Business Combination and otherwise means the
entity which as a result of such Business Combination owns the Company
or all or substantially all the Company's assets either directly or
through one or more subsidiaries; and
(9) the term "Major Asset Disposition" means the sale or
other disposition in one transaction or a series of related
transactions of 70% or more of the assets of the Company and its
subsidiaries on a consolidated basis; and any specified percentage or
portion of the assets of the Company shall be based on fair market
value, as determined by a majority of the Incumbent Directors.
"COMPANY" means Houston Industries Incorporated and any
successor thereto.
"COMPENSATION" means the sum of Executive's annual salary plus
Target Bonus plus Restricted Stock Award, determined immediately prior to (a)
the date on which a Change of Control occurs (or, in the case of an
Anticipatory Change in Employment, immediately prior to the date of the Binding
CIC Agreement) or (b) the time of his Covered Termination, whichever is
greater.
"COVERED TERMINATION" means any termination of Executive's
employment with the Company or any Affiliate thereof, within three years after
the date upon which a Change of Control occurs, which:
(a) results from a resignation by Executive during a
Covered Termination Window; or
(b) does not result from any of (i) death, (ii)
disability entitling Executive to benefits under the Company's
long-term disability plan, (iii) termination on or after age 65, (iv)
termination for Cause or (v) resignation by Executive (except as
described in (a) above).
For this purpose, should a Change in Employment occur (x) after the execution
of a binding agreement to effect a Change of Control (a "Binding CIC
Agreement") and (y) in preparation for or in contemplation of the Change of
Control (an "Anticipatory Change in Employment"), the Change in Employment
shall be treated as if it occurred immediately after the Change of Control.
Any Change in Employment occurring as described in part (x) of the preceding
sentence shall be presumed to satisfy part (y) and be an Anticipatory Change in
Employment unless the Company shall disprove such presumption through clear and
convincing evidence.
"COVERED TERMINATION WINDOW" means the 61-day period
commencing on the date the Executive is subjected to a Change in Employment or,
if later, the date that the Executive becomes aware that he/she has been
subjected to a Change in Employment.
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"RESTRICTED STOCK AWARD" means a cash amount equal to the
maximum amount (stated as a percentage of salary) granted to Executive as a
Restricted Stock Award under the Company's Long Term Incentive Compensation
Plan (or any successor plan) in the applicable calendar year.
"SEVERANCE AMOUNT" means an amount equal to Executive's
Compensation multiplied by 3.
"TARGET BONUS" means Executive's target incentive opportunity
under the Houston Industries Incorporated Executive Incentive Compensation Plan
(or any successor plan) in effect for the year with respect to which the Target
Bonus is being determined or, if no such plan is then in effect, for the last
year in which such a plan was in effect, expressed as a dollar amount based
upon Executive's annual salary for the year of such determination.
"WAIVER AND RELEASE" means a legal document, in the form
attached hereto as Exhibit A or such other form as may be prescribed by the
Company, but which form may not be altered, amended or modified after execution
of a Binding CIC Agreement without the consent of the Executive, in which
Executive, in exchange for severance benefits described in Section 2, among
other things, releases the Company, the Affiliates, their directors, officers,
employees and agents, their employee benefit plans and the fiduciaries and
agents of said plans from liability and damages in any way related to
Executive's employment with or separation from the Company or any of its
Affiliates.
"WELFARE BENEFIT COVERAGE" shall mean each of life insurance,
medical, dental and vision benefits.
2. SEVERANCE BENEFITS: If Executive (a) experiences a Covered
Termination, (b) executes and returns to the Company a Waiver and Release
within a time period prescribed by the Company following the date of
Executive's Covered Termination, and (c) does not revoke such Waiver and
Release within seven days after the date of execution, then Executive shall be
entitled to receive, as additional compensation for services rendered to the
Company (including its Affiliates), the following severance benefits:
(a) CASH LUMP SUM: A lump-sum cash payment in an amount
equal to Executive's Severance Amount, which shall be made within 15
days after expiration of the seven-day Waiver and Release revocation
period.
(b) WELFARE BENEFIT COVERAGES: If, at any time during
the 36-month period following the date of Covered Termination,
Executive is not eligible as a retiree of the Company or its
Affiliates for any Welfare Benefit Coverage, Executive shall be
entitled to obtain such Welfare Benefit Coverage for himself/herself
and, where applicable, his/her eligible dependents, while ineligible
during such period, provided that Executive pays the premiums required
of active employees from time to time for such Welfare Benefit
Coverage. Such entitlement shall apply only to those Welfare Benefit
Coverages that the Company has in effect from time to time for active
employees. Notwithstanding the foregoing, if any Welfare Benefit
Coverage to which the Executive is entitled under this paragraph
cannot be continued during a period
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<PAGE> 6
when Executive is not an employee of the Company, the Company shall
pay to Executive a lump-sum cash payment in an amount equal to the
economic value of such benefit as determined by Deloitte & Touche.
Executive's right to any Welfare Benefit Coverage as a retiree shall
be governed by the applicable plan document in effect from time to
time and shall not be affected by this Agreement.
(c) OUTPLACEMENT: Reimbursement for fees, up to a
maximum amount equal to 15% of Executive's annual base salary as of
the date of his Covered Termination, incurred for outplacement
services within twelve months of the date of Executive's Covered
Termination in connection with Executive's efforts to obtain new
employment.
(d) COMPANY VEHICLE: The option to purchase Executive's
company vehicle, within 30 days following Executive's Covered
Termination, for an amount equal to its depreciated book value as of
the date of Executive's Covered Termination.
(e) BENEFITS RESTORATION PLAN: Benefits (including
"Retirement Plan Restoration Benefits" and "Supplemental Retirement
Benefits"), pursuant to the Benefit Restoration Plan(s) sponsored by
the Company in which Executive is a participant, in an amount not less
than the amount that Executive would have been entitled to receive
pursuant to the underlying qualified retirement plan (a) if Executive
were fully vested in the underlying qualified retirement plan benefits
and (b) had Executive remained in the service of the Company or its
Affiliates throughout the three-year period following the Change of
Control. The Company agrees to amend the Benefit Restoration Plan(s)
to the extent necessary to provide for the payment of these benefits,
which shall be offset by, and not in addition to, any benefit actually
payable pursuant to the qualified retirement plan.
(f) FINANCIAL PLANNING: Continued access, for the
remainder of the calendar year in which the Covered Termination occurs
or for 60 days (if greater), to the financial planning services
available to executive employees at the time of the Change of Control
to which the Covered Termination relates.
3. DEFERRED COMPENSATION PLAN ADMINISTRATION: Notwithstanding
any provision herein or any provision of any Deferred Compensation Plan of the
Company to the contrary, the Company and the Board hereby agree to amend the
Company's Deferred Compensation Plans upon the occurrence of a Change of
Control so that any and all amounts of salary and/or bonus deferred by
Executive and held under the Deferred Compensation Plans shall, upon a Covered
Termination, remain in said plans earning interest at the rate prescribed
therein until paid to or for the benefit of the Executive at such time and in
such form as was irrevocably elected in writing by Executive.
4. CERTAIN ADDITIONAL PAYMENTS: Anything in this Agreement to
the contrary notwithstanding, in the event it shall be determined that any
payment or distribution by the Company to or for the benefit of Executive
(whether paid or payable or distributed or distributable pursuant to
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<PAGE> 7
the terms of this Agreement or otherwise, but determined without regard to any
additional payments required under this Section 4 (a "Payment")) would be
subject to the excise tax imposed by Section 4999 of the Code or any interest
or penalties incurred by Executive with respect to such excise tax (such excise
tax, together with any such interest and penalties, are hereinafter
collectively referred to as the "Excise Tax"), then Executive shall be entitled
to receive an additional payment (a "Gross-Up Payment") in an amount such that
after payment (whether through withholding at the source or otherwise) by
Executive of all taxes (including any interest or penalties imposed with
respect to such taxes), including, without limitation, any income taxes (and
any interest and penalties imposed with respect thereto), employment taxes and
Excise Tax imposed upon the Gross-Up Payment, Executive retains an amount of
the Gross-Up Payment equal to the Excise Tax imposed upon the Payments.
Subject to the provisions of this Section 4, all
determinations required to be made under this Section 4, including whether and
when a Gross-Up Payment is required and the amount of such Gross-Up Payment and
the assumptions to be utilized in arriving at such determination, shall be made
by Deloitte & Touche (the "Accounting Firm") which shall provide detailed
supporting calculations both to the Company and Executive within 15 business
days of the receipt of notice from Executive that there has been a Payment, or
such earlier time as is requested by the Company. In the event that the
Accounting Firm is serving as accountant or auditor for the individual, entity
or group effecting the Change of Control, the Executive shall appoint another
nationally recognized accounting firm to make the determinations required
hereunder (which accounting firm shall then be referred to as the Accounting
Firm hereunder). All fees and expenses of the Accounting Firm shall be borne
solely by the Company. Any Gross-Up Payment, as determined pursuant to this
Section 4, shall be paid by the Company to Executive within five days of the
receipt of the Accounting Firm's determination. If the Accounting Firm
determines that no Excise Tax is payable by Executive, it shall furnish
Executive with a written opinion that failure to report the Excise Tax on
Executive's applicable federal income tax return would not result in the
imposition of negligence or similar penalty. Any determination by the
Accounting Firm shall be binding upon the Company and Executive. As a result
of the uncertainty in the application of Section 4999 of the Code at the time
of the initial determination by the Accounting Firm hereunder, it is possible
that Gross-Up Payments which will not have been made by the Company should have
been made ("Underpayment"), consistent with the calculations required to be
made hereunder. In the event that the Company exhausts its remedies pursuant
to the following provisions of this Section 4 and the Executive thereafter is
required to make a payment of any Excise Tax, the Accounting Firm shall
determine the amount of the Underpayment that has occurred and any such
Underpayment shall be promptly paid by the Company to or for the benefit of
Executive.
Executive shall notify the Company in writing of any claim by
the Internal Revenue Service that, if successful, would require the payment by
the Company of the Gross-Up Payment. Such notification shall be given as soon
as practicable but no later than ten business days after Executive is informed
in writing of such claim and shall apprise the Company of the nature of such
claim and the date on which such claim is requested to be paid. Executive
shall not pay such claim prior to the expiration of the 30-day period following
the date on which it gives such notice to the Company (or such shorter period
ending on the date that any payment of taxes with respect to such claim is
due). If the Company notifies Executive in writing prior to the expiration of
such period that it desires to contest such claim, Executive shall:
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<PAGE> 8
(a) give the Company any information reasonably requested
by the Company relating to such claim;
(b) take such action in connection with contesting such
claim as the Company shall reasonably request in writing from time to
time, including, without limitation, accepting legal representation
with respect to such claim by an attorney reasonably selected by the
Company;
(c) cooperate with the Company in good faith in order to
effectively contest such claim; and
(d) permit the Company to participate in any proceedings
relating to such claim;
provided, however, that the Company shall bear and pay directly all costs and
expenses (including additional interest and penalties) incurred in connection
with such contest and shall indemnify and hold Executive harmless, on an
after-tax basis, for any Excise Tax, employment tax or income tax (including
interest and penalties with respect thereto) imposed as a result of such
representation and payment of costs and expenses. Without limitation of the
foregoing provisions of this Section 4, the Company shall control all
proceedings taken in connection with such contest and, at its sole option, may
pursue or forgo any and all administrative appeals, proceedings, hearings and
conferences with the taxing authority in respect of such claim and may, at its
sole option, either direct Executive to pay the tax claimed and sue for a
refund or contest the claim in any permissible manner, and Executive agrees to
prosecute such contest to a determination before any administrative tribunal,
in a court of initial jurisdiction and in one or more appellate courts, as the
Company shall determine; provided, however, that if the Company directs
Executive to pay such claim and sue for a refund, the Company shall advance the
amount of such payment to Executive, on an interest-free basis and shall
indemnify and hold Executive harmless, on an after-tax basis, from any Excise
Tax, employment tax or income tax (including interest or penalties with respect
thereto) imposed with respect to such advance or with respect to any imputed
income with respect to such advance; and further provided that any extension of
the statute of limitations relating to payment of taxes for the taxable year of
Executive with respect to which such contested amount is claimed to be due is
limited solely to such contested amount. Furthermore, the Company's control of
the contest shall be limited to issues with respect to which a Gross-Up Payment
would be payable hereunder and Executive shall be entitled to settle or
contest, as the case may be, any other issue raised by the Internal Revenue
Service or any other taxing authority.
If, after the receipt by Executive of an amount advanced by
the Company pursuant to the foregoing provisions of this Section 4, Executive
becomes entitled to receive any refund with respect to such claim, Executive
shall (subject to the Company complying with the requirements of this Section
4) promptly pay to the Company the amount of such refund (together with any
interest paid or credited thereon after taxes applicable thereto). If, after
the receipt by Executive of an amount advanced by the Company pursuant to the
foregoing provisions of this Section 4, a determination is made that Executive
shall not be entitled to any refund with respect to such claim and the Company
does not notify Executive in writing of its intent to contest such denial of
refund prior to the expiration of 30 days after such determination, then such
advance shall be forgiven and
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<PAGE> 9
shall not be required to be repaid and the amount of such advance shall offset,
to the extent thereof, the amount of Gross-Up Payment required to be paid.
If the Company is obligated to provide the Executive with one or more
Welfare Benefit Coverages (or a payment in lieu thereof) pursuant to Section
2(b), and the amount of such benefits or the value of such benefit coverage (or
the payment in lieu thereof) (including without limitation any insurance
premiums paid by the Company to provide such benefits) is subject to any
income, employment or similar tax imposed by federal, state or local law, or
any interest or penalties with respect to such tax (such tax or taxes, together
with any such interest and penalties, being hereafter collectively referred to
as the "Income Tax") because such benefits cannot be provided under a
nondiscriminatory health plan described in Section 105 of the Code or for any
other reason, the Company will pay to the Executive an additional payment or
payments (collectively, an "Income Tax Payment"). The Income Tax Payment will
be in an amount such that, after payment by the Executive of all taxes
(including any interest or penalties imposed with respect to such taxes), the
Executive retains an amount of the Income Tax Payment equal to the Income Tax
imposed with respect to such welfare benefits or such welfare benefit coverage.
5. LEGAL FEES AND EXPENSES: It is the intent of the Company that
Executive not be required to incur legal fees and the related expenses
associated with the interpretation, enforcement or defense of Executive's
rights under this Agreement by litigation or otherwise because the cost and
expense thereof would detract from the benefits intended to be extended to
Executive hereunder. Accordingly, if it should appear to Executive that the
Company has failed to comply with any of its obligations under this Agreement
or in the event that the Company or any other person takes or threatens to take
any action to declare this Agreement void or unenforceable, or institutes any
litigation or other action or proceeding designed to deny, or to recover from,
the Executive the benefits provided or intended to be provided to Executive
hereunder, the Company irrevocably authorizes the Executive from time to time
to retain counsel of Executive's choice, at the expense of the Company as
hereafter provided, to advise and represent Executive in connection with any
such interpretation, enforcement or defense, including without limitation the
initiation or defense of any litigation or other legal action, whether by or
against the Company or any director, officer, stockholder or other person
affiliated with the Company, in any jurisdiction. Notwithstanding any existing
or prior attorney-client relationship between the Company and such counsel, the
Company irrevocably consents to Executive entering into an attorney-client
relationship with such counsel, and in that connection the Company and
Executive agree that a confidential relationship will exist between Executive
and such counsel. Without respect to whether Executive prevails, in whole or
in part, in connection with any of the foregoing, the Company will pay and be
solely financially responsible for any and all attorneys' fees and related
expenses incurred by Executive in connection with any of the foregoing except
to the extent that a final judgment no longer subject to appeal finds that a
claim or defense asserted by Executive was frivolous. In such a case, the
portion of such fees and expenses incurred by Executive as a result of such
frivolous claim or defense shall become Executive's sole responsibility and any
funds advanced by the Company or by a Trust created to secure such payment
shall be repaid.
In the event a Change of Control occurs, the performance of
the Company's obligations under this Section 5 will be funded by amounts
deposited or to be deposited in trust pursuant to certain trust agreements to
which the Company will be a party providing that the fees and
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expenses of counsel selected from time to time by Executive pursuant to this
Section 5 will be paid, or reimbursed to Executive if paid by Executive, either
in accordance with the terms of such trust agreements, or, if not so provided,
on a regular, periodic basis upon presentation by Executive to the trustee of a
statement or statements prepared by such counsel in accordance with its
customary practices. In order to be eligible for payment of expenses directly
from the Company, Executive must first exhaust all rights to payment under the
trust agreements contemplated immediately above. The pendency of a claim by
the Company that a claim or defense of Executive is frivolous or otherwise
lacking merit shall not excuse the Company (or the trustee of a Trust
contemplated by this Section 5) from making periodic payments of legal fees
and expenses until a final judgment is rendered as hereinabove provided. Any
failure by the Company to satisfy any of its obligations under this Section 5
will not limit the rights of Executive hereunder. Subject to the foregoing,
Executive will have the status of a general unsecured creditor of the Company
and will have no right to, or security interest in, any assets of the Company
or any Affiliate.
6. NOTICES: For purposes of this Agreement, notices and all
other communications provided for herein shall be in writing and shall be
deemed to have been duly given when personally delivered or when mailed by
United States registered or certified mail, return receipt requested, postage
prepaid, addressed as follows:
If to Company: Houston Industries Incorporated
P.O. Box 4567
Houston, Texas 77210
ATTENTION: Chairman of the Board
If to Executive:
--------------------------
--------------------------
--------------------------
or to such other address as either party may furnish to the other in writing
in accordance herewith, except that notices of changes of address shall be
effective only upon receipt.
7. APPLICABLE LAW: The validity, interpretation, construction
and performance of this Agreement will be governed by and construed in
accordance with the substantive laws of the State of Texas, including the Texas
statute of limitations, but without giving effect to the principles of conflict
of laws of such State.
8. SEVERABILITY: If a court of competent jurisdiction determines
that any provision of this Agreement is invalid or unenforceable, then the
invalidity or unenforceability of that provision shall not affect the validity
or enforceability of any other provision of this Agreement and all other
provisions shall remain in full force and effect.
9. WITHHOLDING OF TAXES: The Company may withhold from any
benefits payable under this Agreement all federal, state, city or other taxes
as may be required pursuant to any law or governmental regulation or ruling.
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10. NO EMPLOYMENT AGREEMENT: Nothing in this Agreement shall give
Executive any rights to (or impose any obligations for) continued employment by
the Company or any Affiliate thereof or successor thereto, nor shall it give
the Company any rights (or impose any obligations) with respect to continued
performance of duties by Executive for the Company or any Affiliate thereof or
successor thereto.
11. NO ASSIGNMENT; SUCCESSORS: Executive's right to receive
payments or benefits hereunder shall not be assignable or transferable, whether
by pledge, creation or a security interest or otherwise, whether voluntary,
involuntary, by operation of law or otherwise, other than a transfer by will or
by the laws of descent or distribution, and in the event of any attempted
assignment or transfer contrary to this Section 11 the Company shall have no
liability to pay any amount so attempted to be assigned or transferred. This
Agreement shall inure to the benefit of and be enforceable by Executive's
personal or legal representatives, executors, administrators, successors,
heirs, distributees, devisees and legatees.
This Agreement shall be binding upon and inure to the benefit
of the Company, its successors and assigns (including, without limitation, any
company into or with which the Company may merge or consolidate). The Company
agrees that it will not effect the sale or other disposition of all or
substantially all of its assets unless either (a) the person or entity
acquiring such assets or a substantial portion thereof shall expressly assume
by an instrument in writing all duties and obligations of the Company hereunder
or (b) the Company shall provide, through the establishment of a separate
reserve therefor, for the payment in full of all amounts which are or may
reasonably be expected to become payable to Executive hereunder.
12. PAYMENT OBLIGATIONS ABSOLUTE: Except for the requirement of
the Executive to execute and return to the Company a Waiver and Release in
accordance with Section 2, the Company's obligation to pay (or cause one of its
Affiliates to pay) Executive the amounts and to make the arrangements provided
herein shall be absolute and unconditional and shall not be affected by any
circumstances, including, without limitation, any set-off, counter-claim,
recoupment, defense or other right which the Company (including its Affiliates)
may have against him/her or anyone else. All amounts payable by the Company
(including its Affiliates hereunder) shall be paid without notice or demand.
Executive shall not be obligated to sign an agreement not to compete with the
Company or to seek other employment in mitigation of the amounts payable or
arrangements made under any provision of this Agreement, and the obtaining of
any other employment shall in no event effect any reduction of the Company's
obligations to make (or cause to be made) the payments and arrangements
required to be made under this Agreement.
13. NUMBER AND GENDER: Wherever appropriate herein, words used in
the singular shall include the plural and the plural shall include the
singular. The masculine gender where appearing herein shall be deemed to
include the feminine gender.
14. TERM: The effective date of the Agreement is September 3,
1997. The term of this Agreement shall be for a period of three years after
such effective date.
15. EXTENSION: The Board or the Executive Committee of the
Company may, at any time prior to the expiration hereof, extend the term hereof
for a period of up to three years from the
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date on which such extension is approved, without any further action on the
part of Executive or the Company.
IN WITNESS WHEREOF, the parties have caused this Agreement to
be executed and delivered this _____ day of November, 1997, but effective as of
the day and year first above written.
HOUSTON INDUSTRIES INCORPORATED
By______________________________________
Don D. Jordan,
Chairman and Chief Executive Officer
EXECUTIVE
________________________________________
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[REI -- EXHIBIT 10(b)(b)]
EMPLOYMENT AGREEMENT
THIS EMPLOYMENT AGREEMENT ("Agreement") is made and effective
as of the 16th day of February, 1998, by and between HOUSTON INDUSTRIES
INCORPORATED, a Texas corporation having its principal place of business in
Houston, Harris County, Texas ("Company"), and CHARLES OGLESBY, an individual
currently residing in Harris County, Texas ("Executive").
1. Employment of Executive: In consideration of the mutual covenants
and agreements herein contained, the Company and Executive wish to establish a
three year Employment Agreement retaining Executive's services as described
herein, establishing certain incentive, tenure and performance criteria related
to such employment and otherwise fixing Executive's benefits, base salary and
incentive compensation on a basis comparable to that of other members of senior
management of the Company. A principal objective of this Agreement is to
facilitate the full integration of Executive into the senior management
structure of the Company.
2. Term and Extent of Services: During the Term, as defined below,
Executive shall be employed as President and Chief Operating Officer of Houston
Industries Trading & Transportation Group ("HITTG") and as Senior Vice
President of the Company and shall have all of the rights, powers and duties
associated with those positions. During the Term, Executive agrees to devote
his services full-time to the business of the Company and to perform to the
best of his ability and with reasonable diligence the duties and
responsibilities assigned to him by the appropriate management of the Company.
The term hereof shall commence February 16, 1998 (the "Effective Date") and
shall continue thereafter through February 15, 200l (the "Term").
3. Compensation and Benefits:
(a) Salary: During the Term, Executive's salary shall be not less
than $375,000 per year, and shall be increased during the Term at the same time
and on the same basis as other senior executives.
(b) Benefits: During the Term, the Executive shall be eligible to
participate in all of the Company's general and executive compensation and
benefit plans on a basis comparable to other similarly situated members of
senior management, including the Houston Industries Incorporated Executive
Severance Benefits Plan, the current form of Agreement for which is annexed
hereto as Enclosure 1.
(c) Supplemental Retirement Benefit: If the aggregate monthly
retirement benefit actually payable to Executive from all defined benefit
pension plans and supplemental executive retirement plans in which the
Executive participates as of the Effective Date, or any successor plans thereto
(the "Actual Benefit"), when calculated in the form of a single life annuity,
is less than $2,619.24 commencing at age 52, or $6,084.18 commencing at or
after age 62, prorated for commencement at any age between 52 and 62 (the
"Guaranteed Benefit"), the Company shall pay a supplemental retirement benefit
to the Executive from its general assets in the amount of the
-1-
<PAGE> 2
difference between the Actual Benefit and the Guaranteed Benefit. Any
supplemental retirement benefit payable hereunder shall be paid in such form
and at such times as the Actual Benefit is paid.
4. Additional Incentive Compensation: The Company recognizes
Executive's area of responsibility as a strategically critical one for its
future growth in the converging businesses of gas and electric transportation,
supply and services. The HITTG division of the Company provides a full range of
energy and risk management services through pipeline, gathering, trading, and
marketing affiliates. The successful direction of these activities is
essential. Additionally, the Company and its competitors continue to encounter
significant difficulty attracting and retaining personnel at all levels in
these fields, which has placed additional importance on personnel retention and
management of this division. Therefore, as additional incentive for the
Executive to remain in the employ of the Company during the Term and to use his
best efforts to enhance the value of the Company during the Term, the Company
shall pay to the Executive a special two year Retention Bonus. The Retention
Bonus shall be paid in three installments: $475,000 on February 15, 1999,
$400,000 on August 15, 1999, and $400,000 on February 15, 2000.
5. Termination of Employment: Should Executive's employment terminate
prior to the end of the Term, the following provisions of this Section 5 shall
govern the rights of the Executive under this Agreement:
(a) Termination Due to Death: In the event the Executive's
employment terminates during the Term as a result of the Executive's death, the
Company agrees (i) to pay all compensation that would have been payable to the
Executive under Sections 3(a) and 4 hereof during the remainder of the Term
(had the Executive's employment continued during the remainder of the Term) to
the Executive's beneficiary or beneficiaries under the group life insurance
plan then sponsored by the Company and (ii) to continue to provide, during the
remainder of the Term, all welfare benefit coverages that were provided under
Section 3(b) to the Executive's legal spouse and children on the date of his
death.
(b) Termination Due to Disability: In the event the Executive's
employment is terminated during the Term due to his disability within the
meaning of any long-term disability plan maintained by the Company and covering
the Executive as of the date of Executive's disability, the Company agrees (i)
to pay Executive all compensation that would have been payable to the Executive
under Sections 3(a) and 4 hereof during the remainder of the Term (had the
Executive's employment continued during the remainder of the Term) and (ii) to
continue to provide, during the remainder of the Term, all welfare benefit
coverages that were provided under Section 3(b) to or in respect of the
Executive on the date of his disability, in addition to the benefits payable
under the long-term disability plan; provided, however, that any salary due
under clause (i) of this sentence shall be reduced by the amount of any
long-term disability benefit actually paid to the Executive during the Term. It
is the intention of this paragraph (b) that the total of disability payments
and base salary paid to the Executive during the Term shall equal but not
exceed the Executive's base salary payable during the Term.
(c) Termination by the Company for Cause: Any termination of the
Executive's employment by the Company for Cause shall be authorized by a vote
of at least a majority of the members of the Board and effected by written
notice to the Executive within 12 months of a majority
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<PAGE> 3
of the members of the Board having actual knowledge of the event or
circumstances providing a basis for such termination. In the event the Company
terminates the Executive's employment during the Term for Cause, he shall be
entitled to:
(i) his base salary through the date of the term-
ination of his employment for Cause;
(ii) any other amounts earned, accrued or owing as
of the date of termination of employment but not yet
paid as compensation by the Company under Section 3(b)
above; and
(iii) other benefits for which he is eligible in
accordance with applicable plans or programs of the
Company.
In addition, should Executive elect to contest any claimed discharge for Cause,
he may demand the immediate payment, as liquidated damages and not as a
penalty, of any unpaid Retention Bonuses and tender to the Company an executed
release in the form attached hereto as Exhibit A to Enclosure 1, in which event
Company shall make such payment forthwith and release Executive from all claims
it may have had against Executive; provided, however, that Company shall be
required to make payment upon receipt of such executed release but shall not be
required to cross release Executive from any damage claims alleged to have
resulted from intentional or morally corrupt conduct of a type not insurable
under commercially-available Directors' and Officers liability policies.
"CAUSE" means Executive's (i) Gross Negligence in the performance
of his duties, (ii) intentional and continued failure to perform his duties,
(iii) intentional engagement in conduct which is materially injurious to the
Company or its affiliates (monetarily or otherwise) or (iv) conviction of a
felony or a misdemeanor involving moral turpitude. For this purpose, an act or
failure to act on the part of Executive will be deemed "intentional" only if
done or omitted to be done by Executive not in good faith and without
reasonable belief that his/her action or omission was in the best interest of
the Company, and no act or failure to act on the part of Executive will be
deemed "intentional" if it was due primarily to an error in judgment or
ordinary negligence.
"GROSS NEGLIGENCE" as used herein carries the meaning used in
Texas law as of the Effective Date, which requires a specific intent by
Executive to cause substantial damage to the Company or an act or omission
which, when viewed objectively from the standpoint of the Executive at the time
in question, involves an extreme degree of risk, considering the probability
and magnitude of the potential harm to the Company; and of which the Executive
has actual, subjective awareness of the risk involved, but nevertheless
proceeds with conscious indifference to the rights or welfare of the Company.
(d) Termination Without Cause or Voluntarily with Good Reason: In
the event that, during the Term, the Company terminates the Executive's
employment without Cause (other than due to disability or death) or the
Executive voluntarily terminates employment for Good Reason, the Company agrees
to pay Executive all amounts that would have been payable hereunder and to
continue to provide all benefit coverages provided hereunder to the end of the
Term. The failure of the Executive to terminate employment upon the occurrence
of Good Reason as to any one event
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<PAGE> 4
constituting Good Reason shall not affect his entitlement to terminate his
employment as to any other such event.
"GOOD REASON" means:
(i) the assignment to the Executive of any duties
inconsistent with the Executive's employment position
contemplated by Section 2, or any other action by the
Company which results in a diminution in the authority,
duties or responsibilities attendant to such position,
excluding any action not taken in bad faith that is
remedied by the Company promptly after receipt of notice
thereof from the Executive;
(ii) any failure by the Company to comply with any of
the provisions of Section 3(a), other than any failure
not occurring in bad faith that is remedied by the
Company promptly after receipt of notice thereof from
the Executive;
(iii) relocation, without the Executive's consent,
of the Executive's principal office to any office or
location more than 50 miles from the principal office of
the Executive on the Effective Date; or
(iv) any failure by the Company to comply with and
satisfy the final paragraph of Section 11, provided that
the successor described in Section 11 has received at
least ten days' prior written notice from the Company or
the Executive of the requirements of Section 11.
(e) Voluntary Termination: Upon 30 days' prior notice to the
Company, the Executive may voluntarily terminate his employment with the
Company. A voluntary termination pursuant to this Section 5(e) shall not
include termination under Section 5(a), 5(b) or 5(d) above, and shall not be
deemed a breach of the Agreement by the Executive. In the event the Executive
voluntarily terminates his employment, he shall be entitled to:
(i) his base salary through the date of the term-
ination of his employment;
(ii) any other amounts earned, accrued or owing as
of the date of termination of employment but not yet
paid as compensation by the Company under Section 3(b)
above; and
(iii) other benefits for which he is eligible in
accordance with applicable plans or programs of the
Company.
(f) Certain Benefit Calculations: Upon termination of
employment pursuant to Section 5(b) or 5(d), for purposes of any eligibility
and benefit determinations under all benefit plans maintained by the Company
and applicable to the Executive or his beneficiaries upon such termination, and
for purposes of eligibility for retiree medical coverage, (i) Executive will be
credited with service for the period remaining in the Term (the "Remaining
Term"), (ii) Executive's age on the last day of the Term shall be deemed to
have been his age at the date of actual termination of
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<PAGE> 5
employment, and (iii) payments made pursuant to Sections 3(a) and 4 shall be
treated as employment compensation paid during the Remaining Term.
(g) No Mitigation; No Offset: In the event of any termination
of employment under this Section 5, the Executive shall be under no obligation
to seek other employment, and there shall be no offset against amounts due the
Executive under this Agreement on account of any remuneration attributable to
any subsequent employment that he may obtain.
(h) Nature of Payments: Any amounts due under this Section 5
are in the nature of severance payments, liquidated damages, or both, and shall
compensate the Executive, and the dependents, beneficiaries and estate of the
Executive for any and all direct damages and consequential damages that they
may suffer as a result of the termination of the Executive's employment, and
are not in the nature of a penalty.
6. Fresh Start: In consideration of Executive's full and general
release (in the form annexed hereto as Enclosure 2) of all existing rights and
claims with respect to the Company and its wholly owned subsidiaries, the
Company agrees to pay Executive a lump sum settlement of $1,000,000. The lump
sum payment shall be made at the end of the next full pay period following the
execution of this Agreement, provided that the Executive delivers the required
executed release to the Company concurrently with the receipt of such payment.
7. Notices: For purposes of this Agreement, notices and all other
communications provided for herein shall be in writing and shall be deemed to
have been duly given when personally delivered or when mailed by United States
registered or certified mail, return receipt requested, postage prepaid,
addressed as follows:
<TABLE>
<S> <C>
If to Company: Houston Industries Incorporated
P.O. Box 4567
Houston, Texas 77210
ATTENTION: Chairman of the Board
If to Executive: ----------------------------------
----------------------------------
----------------------------------
</TABLE>
or to such other address as either party may furnish to the other in writing in
accordance herewith, except that notices of changes of address shall be
effective only upon receipt.
8. Applicable Law: The validity, interpretation, construction and
performance of this Agreement will be governed by and construed in accordance
with the substantive laws of the State of Texas, including the Texas statute of
limitations, but without giving effect to the principles of conflict of laws of
such State.
9. Severability: If a court of competent jurisdiction determines that
any provision of this Agreement is invalid or unenforceable, then the
invalidity or unenforceability of that provision shall
-5-
<PAGE> 6
not affect the validity or enforceability of any other provision of this
Agreement and all other provisions shall remain in full force and effect.
10. Withholding of Taxes: The Company may withhold from any benefits
payable under this Agreement all federal, state, city or other taxes as may be
required pursuant to any law or governmental regulation or ruling. However, any
taxes of the type described in Section 4 of the Enclosure 1 shall be treated as
if imposed on payments thereunder and such provisions are incorporated herein
for such purposes as if set forth fully in this Agreement.
11. No Assignment; Successors: Executive's right to receive payments
or benefits hereunder shall not be assignable or transferable, whether by
pledge, creation or a security interest or otherwise, whether voluntary,
involuntary, by operation of law or otherwise, other than a transfer by will or
by the laws of descent or distribution, and in the event of any attempted
assignment or transfer contrary to this Section 11 the Company shall have no
liability to pay any amount so attempted to be assigned or transferred. This
Agreement shall inure to the benefit of and be enforceable by Executive's
personal or legal representatives, executors, administrators, successors,
heirs, distributes, devises and legatees.
This Agreement shall be binding upon and inure to the benefit
of the Company, its successors and assigns (including, without limitation, any
company into or with which the Company may merge or consolidate). The Company
agrees that it will not effect the sale or other disposition of all or
substantially all of its assets unless either (a) the person or entity
acquiring such assets or a substantial portion thereof shall expressly assume
by an instrument in writing all duties and obligations of the Company hereunder
or (b) the Company shall provide, through the establishment of a separate
reserve therefor, for the payment in full of all amounts which are or may
reasonably be expected to become payable to Executive hereunder.
12. Payment Obligations Absolute: Except for the requirement of the
Executive to execute and return to the Company a Waiver and Release in
accordance with Sections 5 and 6, the Company's obligation to pay (or cause one
of its Affiliates to pay) Executive the amounts and to make the arrangements
provided herein shall be absolute and unconditional and shall not be affected
by any circumstances, including, without limitation, any set-off,
counter-claim, recoupment, defense or other right which the Company (including
its Affiliates) may have against him or anyone else. All amounts payable by the
Company (including its Affiliates hereunder) shall be paid without notice or
demand. Executive shall not be obligated to sign an agreement not to compete
with the Company or to seek other employment in mitigation of the amounts
payable or arrangements made under any provision of this Agreement, and the
obtaining of any other employment shall in no event effect any reduction of the
Company's obligations to make (or cause to be made) the payments and
arrangements required to be made under this Agreement.
-6-
<PAGE> 7
IN WITNESS WHEREOF, the parties have caused this Agreement to be
executed and delivered the _____ day of February, 1998, but effective as of the
day and year first above written.
HOUSTON INDUSTRIES INCORPORATED
By /s/ DON D. JORDAN
------------------------------------
Don D. Jordan,
Chairman and Chief Executive Officer
EXECUTIVE
/s/ CHARLES OGLESBY
--------------------------------------
Charles Oglesby
-7-
<PAGE> 8
WAIVER AND RELEASE
Houston Industries Incorporated has offered to pay me $1,000,000.00
(the "Payment") in exchange for my agreement to waive all of my claims against
and release Houston Industries Incorporated and its predecessors, successors
and assigns (collectively referred to as the "Company"), all of the affiliates
(including subsidiaries) of the Company (collectively referred to as the
"Affiliates") and the Company's and Affiliates' directors and officers,
employees and agents, insurers, named employee benefit plans and contracts, and
the fiduciaries and agents of said plans (collectively, with the Company and
Affiliates, referred to as the "Corporate Group") from any and all claims,
demands, actions, liabilities, damages and contractual obligations that arise
in any way from my employment with the Company or the Affiliates through the
date identified as my signature date at the end of this Waiver and Release
("Signature Date"). This payment is voluntary on the part of the Company and is
not a legal obligation of any member of the Corporate Group. I choose to accept
this offer.
In exchange for the Payment, which is in addition to any remuneration
or benefits to which I am already entitled, (1) I agree not to sue in any local,
state and/or federal court regarding or relating in any way to my employment
with the Company or the Affiliates through the Signature Date, and (2) I
knowingly and voluntarily (a) waive all rights and claims I have, as of the
Signature Date, with respect to any member of the Corporate Group and (b)
release the Corporate Group from any and all liabilities, damages and
contractual obligations to me (directly or as a third party beneficiary),
whether known or unknown, matured or unmatured, contingent or absolute, that
stem in any way from my employment with the Company or the Affiliates through
the Signature Date, except for my rights under the terms of any employee benefit
plans sponsored by the Company or the Affiliates that are not named below. This
Waiver and Release includes, but is not limited to, all contractual obligations,
rights, claims and causes of action under: Title VII of the Civil Rights Act of
1964, as amended; the Age Discrimination in Employment Act of 1967, as amended,
including the Older Workers Benefit Protection Act of 1990; the Civil Rights Act
of 1866, as amended; the Civil Rights Act of 1991; the Americans with
Disabilities Act of 1990; the Energy Reorganization Act, as amended, 42 U.S.C.
Section 5851; the Workers Adjustment and Retraining Notification Act of 1988;
the Pregnancy Discrimination Act of 1978; the Employee Retirement Income
Security Act of 1974, as amended; the Family and Medical Leave Act of 1993; the
Fair Labor Standards Act; the Occupational Safety and Health Act; the Texas
Labor Code Section 21.001 et. seq.; the Texas Labor Code; any of the following
employee benefit plans: the Arkla, Inc. and Subsidiaries Nonqualified Executive
Disability Income Plan, the Diversified Energies Inc. Benefit Equalization and &
Savings Plan, the NorAm Executive Severance Benefits Plan, the Arkla, Inc. Long
Term Incentive Compensation Plan, the NorAm Energy Corp. 1994 Incentive Equity
Plan, the DEI 1990 Stock Award Plan, the NorAm 1997 All Employee Incentive Plan,
and any contract relating in any way to any such plan; the Agreement and Plan of
Merger among the Company, Houston Lighting & Power Company, HI Merger, Inc. and
NorAm Energy Corp. dated as of August 11, 1996; claims in connection with
workers' compensation or "whistle blower" status; and/or contract, tort,
defamation, slander, wrongful termination or any other state or federal
regulatory, statutory or common law. I understand that this Waiver and Release
shall operate as a full and final and complete release and settlement of any and
all claims under any of the foregoing.
-1-
<PAGE> 9
I expressly represent that no promise or agreement which is not
expressed in this Waiver and Release has been made to me in executing this
Waiver and Release, and that I am relying on my own judgment in executing this
Waiver and Release, and I am not relying on any statement or representation of
any member of the Corporate Group or any of their agents. I agree that this
Waiver and Release is valid, fair, adequate and reasonable, is with my full
knowledge and consent, was not procured through fraud, duress, or mistake and
has not had the effect of misleading, misinforming or failing to inform me. I
acknowledge that Payment is not an admission by the Company that the Company or
any other member of the Corporate Group engaged in any wrongful or unlawful act
or violated any law or regulation. I understand that nothing in this Waiver and
Release is intended to prohibit, restrict or otherwise discourage any individual
from engaging in activity protected under 42 U.S.C. Section 5851 and 10 C.F.R.
Section 50.7, including, but not limited to, providing information to the
Nuclear Regulatory Commission ("NRC") or to the Company regarding nuclear safety
or quality concerns, potential violations or other matters within the NRC's
jurisdiction.
I acknowledge that this Waiver and Release sets forth the entire
understanding and agreement between me and the Corporate Group concerning the
subject matter of this Waiver and Release and supersede any prior or
contemporaneous oral and/or written agreements or representations, if any,
between me and the Corporate Group with respect to that subject matter. I
understand that signing this Waiver and Release is an important legal act. I
acknowledge that the Company has advised me in writing to consult an attorney
before signing this Waiver and Release. I acknowledge that I have read this
Waiver and Release, have had an opportunity to ask questions and have it
explained to me and that I understand that this Waiver and Release will have
the effect of knowingly and voluntarily waiving any action I might pursue,
including breach of contract, personal injury, retaliation, discrimination on
the basis of race, age, sex, national origin, or disability and any other
claims arising prior to the date of this Waiver and Release. By execution of
this document, I do not waive or release or otherwise relinquish any legal
rights I may have which are attributable to or arising out of acts, omissions,
or events of the Company or any other member of the Corporate Group which occur
after the date of the execution of this Waiver and Release.
Should any of the provisions set forth in this Waiver and Release be
determined to be invalid by a court, agency or other tribunal of competent
jurisdiction, it is agreed that such determination shall not effect the
enforceability of other provisions of this Waiver and Release.
/s/ CHARLES OGLESBY
- -------------------------------------
Charles Oglesby
3/4/98
- -------------------------------------
Signature Date
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<PAGE> 1
[REI - EXHIBIT No. 10(c)(c)]
HOUSTON INDUSTRIES INCORPORATED
SAVINGS PLAN
(As Amended and Restated Effective as of July 1, 1995)
Fifth Amendment
The Benefits Committee of Houston Industries Incorporated, having the
right under Section 10.3 of the Houston Industries Incorporated Savings Plan,
as amended and restated effective July 1, 1995 and thereafter amended (the
"Plan"), to amend the Plan, does hereby amend Section 7.4(c) of the Plan as
follows, effective October 15, 1997:
"7.4(c) In the event an installment payment is not paid within ninety
days following the last regular payroll for which a payment was
received, written notice shall be sent to the Borrower at his last
known address. If such installment payment is not made within 30 days
thereafter, the Committee or its agent shall proceed with foreclosure
in order to collect the full remaining loan balance or shall make
other arrangements with the Borrower as the Committee deems
appropriate. Foreclosures need not be effected until occurrence of a
distributable event under the terms of the Plan and no rights against
the Borrower or the security shall be deemed waived by the Plan as a
result of such delay."
IN WITNESS WHEREOF, the Benefits Committee of Houston Industries
Incorporated has caused these presents to be executed by its duly authorized
Chairman in a number of copies, all of which shall constitute one and the same
instrument, which may be sufficiently evidenced by any
1
<PAGE> 2
executed copy hereof, this 26th day of February, 1998, but effective as of
October 15, 1997.
BENEFITS COMMITTEE OF
HOUSTON INDUSTRIES INCORPORATED
By: /s/ Lee W. Hogan
--------------------------------
Lee W. Hogan, Chairman
ATTEST:
/s/ Elizabeth P. Weylandt
- -------------------------
Elizabeth P. Weylandt,
Secretary of the Benefits Committee
2
<PAGE> 1
[REI - EXHIBIT 10(d)(d)]
HOUSTON INDUSTRIES ENERGY, INC.
LONG-TERM PROJECT INCENTIVE COMPENSATION PLAN
(As Established Effective January 1, 1994)
Fourth Amendment
Houston Industries Incorporated, a Texas corporation, having
established the Houston Industries Energy, Inc. Long-Term Project Incentive
Compensation Plan, effective January 1, 1994 (the "Plan"), and having reserved
the right under Article XIV thereof to amend the Plan, does hereby amend the
second sentence of Article IX.B of the Plan, effective January 1, 1997, to read
as follows:
"Long-Term Awards (including any Long-Term Awards previously awarded
under the Plan) will be paid as soon as practicable following the
completion of three years from the first day of the Plan Year to which
they relate, upon the Compensation Committee's determination that the
Performance Goals previously established with respect to such Award
have been satisfied and subject to the remaining provisions of this
Article IX."
IN WITNESS WHEREOF, Houston Industries Incorporated has caused these
presents to be executed by its duly authorized officers in a number of copies,
all of which shall constitute one and the same instrument, which may be
sufficiently evidenced by any executed copy hereof, this 26th day of February,
1998, but effective as of the date herein stated.
HOUSTON INDUSTRIES INCORPORATED
By: /s/ Lee W. Hogan
-----------------------------------------
Name: Lee W. Hogan
----------------------------------
Title: Executive Vice President
---------------------------------
ATTEST:
/s/ Richard B. Dauphin
- ---------------------------------
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<PAGE> 1
[REI - EXHIBIT No. 10(e)(e)]
HOUSTON INDUSTRIES INCORPORATED
STOCK PLAN FOR OUTSIDE DIRECTORS
First Amendment
Houston Industries Incorporated, a Texas corporation (the "Company"),
having adopted the Houston Industries Incorporated Stock Plan for Outside
Directors, effective May 22, 1996 (the "Plan"), and having reserved the right
under Section 6.1 thereof to amend the Plan, does hereby amend the Plan,
effective as of August 6, 1997, to read as follows:
1. The first sentence of Article I of the Plan is hereby amended to
read as follows:
"The purpose of this Houston Industries Incorporated Stock Plan
for Outside Directors (the 'Plan') is to provide for a method of
compensation of Outside Directors of Houston Industries Incorporated
and any successor thereto (the 'Company') that will strengthen the
alignment of their financial interests with those of the Company's
shareholders through increased ownership of shares of the Company's
Common Stock by such Outside Directors."
2. The definition of "Company" in Article II is hereby amended in its
entirety to read as follows:
"COMPANY means Houston Industries Incorporated, a Texas
corporation, and any successor thereto."
IN WITNESS WHEREOF, Houston Industries Incorporated has caused this
Amendment to be executed by its duly authorized officers this 26th day of
February, 1998, but effective as of August 6, 1997.
HOUSTON INDUSTRIES INCORPORATED
By: /s/ Lee W. Hogan
-----------------------------------------
Name: Lee W. Hogan
-----------------------------------
Title: Executive Vice President
----------------------------------
ATTEST:
/s/ Richard B. Dauphin
- ------------------------------------
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<PAGE> 1
[REI-EXHIBIT 12]
HOUSTON INDUSTRIES INCORPORATED AND SUBSIDIARIES
D/B/A RELIANT ENERGY INCORPORATED AND SUBSIDIARIES
COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
TWELVE MONTHS ENDED DECEMBER 31,
-----------------------------------------------------------------
1998 1997 1996 1995 1994
----------- ----------- ----------- ---------- ----------
Fixed Charges as Defined:
<S> <C> <C> <C> <C> <C>
(1) Interest on Long-Term Debt............... $ 416,138 $ 320,845 $ 276,242 $ 279,491 $ 265,494
(2) Other Interest........................... 97,767 77,112 33,738 21,586 25,076
(3) Capitalized Interest..................... 9,565 7,721
(4) Distribution on Trust Securities......... 29,201 26,230
(5) Preferred Dividends Factor of Subsidiary. 0 3,360 33,619 44,933 51,718
(6) Interest Component of Rentals Charged to
Operating Expense......................... 9,966 5,692 942 3,102 3,951
----------- ----------- ----------- ---------- ----------
(7) Total Fixed Charges...................... $ 562,637 $ 440,960 $ 344,541 $ 349,112 $ 346,239
=========== =========== =========== ========== ==========
Earnings as Defined:
(8) Income from Continuing Operations........ $ (141,092) $ 421,110 $ 404,944 $ 397,400 $ 423,985
(9) Income Taxes for Continuing Operations... (30,432) 206,374 $ 200,165 199,555 230,424
(10) Fixed Charges (line 7)................... 562,637 440,960 $ 344,541 349,112 346,239
(11) Capitalized Interest (Line 3)............ (9,565) (7,721)
----------- ----------- ----------- ---------- ----------
(12) Income from Continuing Operations Before
Income Taxes and Fixed Charges............ $ 381,548 $ 1,060,723 $ 949,650 $ 946,067 $1,000,648
=========== =========== =========== ========== ==========
Preferred Dividends Factor of Subsidiary:
(13) Preferred Stock Dividends of Subsidiary.. $ 0 $ 2,255 $ 22,563 $ 29,955 $ 33,583
(14) Ratio of Pre-Tax Income from Continuing
Operations to Income from Continuing
Operations(line 8 plus line 9 divided,
(line 8).................................. 1.22 1.49 1.49 1.50 1.54
----------- ----------- ----------- ---------- ----------
(15) Preferred Dividends Factor of Subsidiary
(line 14 times line 13)................... $ 0 $ 3,360 $ 33,619 $ 44,933 $ 51,718
=========== =========== =========== ========== ==========
Ratio of Earnings from Continuing Operations to
Fixed Charges Before Cumulative Effect of
Change in Accounting (line 12 divided by line
7)............................................. 2.41 2.76 2.71 2.89
</TABLE>
In 1998 earnings are inadequate to cover fixed charges by approximately $181
million. This deficiency results from the $1.2 billion non-cash, unrealized
accounting loss recorded for the ACES. Excluding the effect of the non-cash,
unrealized accounting loss of $764 million, the ratio of earnings from the
continuing operations to fixed charges would have been 2.77.
172
<PAGE> 1
[REI -- EXHIBIT 21]
SIGNIFICANT SUBSIDIARIES OF HOUSTON INDUSTRIES INCORPORATED
d/b/a RELIANT ENERGY, INCORPORATED
The following subsidiaries are deemed "significant subsidiaries" pursuant
to Item 601(b)(21) of Regulation S-K:
Reliant Energy Resources Corp., a Delaware corporation and a wholly owned
subsidiary of Houston Industries Incorporated.
Reliant Energy International, Inc., a Delaware corporation and a
wholly-owned subsidiary of Houston Industries Incorporated.
- ----------
(1) Pursuant to Item 601(b)(21) of Regulation SK, registrant has omitted the
names of subsidiaries, which considered in the aggregate as a single
subsidiary, would not constitute a "significant subsidiary" (as defined
under Rule 1-02(w) of Regulation S-X) as of December 31, 1997
(2) Reliant Energy Resources Corp. also conducts business under the names of
its three unincorporated divisions: Reliant Energy Arkla, Reliant Energy
Entex and Reliant Energy Minnegasco
<PAGE> 1
[REI -- EXHIBIT 23]
INDEPENDENT AUDITORS' CONSENT
We consent to the incorporation by reference in Houston Industries
Incorporated's, d/b/a Reliant Energy, Incorporated (i) Registration Statement on
Form S-4 No. 333-11329, (ii) Registration Statements on Form S-3 Nos. 33-46368,
33-54228, 333-20069, 333-32353, 333-33301, 333-33303, 333-58433, and 333-70665,
(iii) Post-Effective Amendment No. 1 to Registration Statement No. 33-51417 on
Form S-3, (iv) Registration Statements on Form S-8 Nos. 333-32413, 333-32585,
and 333-49333 and (v) Post-Effective Amendments Nos. 1 and 2 to Registration
Statement No. 333-11329-99 on Form S-8 of our report dated February 25, 1999
(relating to the consolidated financial statements of Houston Industries
Incorporated d/b/a Reliant Energy, Incorporated (the "Company")) appearing in
this Combined Annual Report on Form 10-K of the Company and Reliant Energy
Resources, formerly NorAm Energy Corp. for the year ended December 31, 1998.
Deloitte & Touche LLP
Houston, Texas
March 18, 1999
<TABLE> <S> <C>
<ARTICLE> OPUR1
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
COMPANY'S FINANCIAL STATEMENTS AND IS QUALIFIED IN ITS ENTIRETY BY
REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<CIK> 0000048732
<NAME> HOUSTON INDUSTRIES INCORPORATED
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> DEC-31-1998
<BOOK-VALUE> PRO-FORMA
<TOTAL-NET-UTILITY-PLANT> 9,664,110
<OTHER-PROPERTY-AND-INVEST> 3,908,631
<TOTAL-CURRENT-ASSETS> 1,669,171
<TOTAL-DEFERRED-CHARGES> 3,896,610
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 19,138,522
<COMMON> 2,916,662
<CAPITAL-SURPLUS-PAID-IN> 0
<RETAINED-EARNINGS> 1,395,466
<TOTAL-COMMON-STOCKHOLDERS-EQ> 4,312,128
0
9,740
<LONG-TERM-DEBT-NET> 7,142,980
<SHORT-TERM-NOTES> 0
<LONG-TERM-NOTES-PAYABLE> 452,500
<COMMERCIAL-PAPER-OBLIGATIONS> 1,360,239
<LONG-TERM-DEBT-CURRENT-PORT> 397,454
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 5,463,481
<TOT-CAPITALIZATION-AND-LIAB> 19,138,522
<GROSS-OPERATING-REVENUE> 11,488,464
<INCOME-TAX-EXPENSE> (30,432)
<OTHER-OPERATING-EXPENSES> 10,011,076
<TOTAL-OPERATING-EXPENSES> 10,011,076
<OPERATING-INCOME-LOSS> 1,477,388
<OTHER-INCOME-NET> (1,110,110)
<INCOME-BEFORE-INTEREST-EXPEN> 368,278
<TOTAL-INTEREST-EXPENSE> 538,802
<NET-INCOME> (141,092)
390
<EARNINGS-AVAILABLE-FOR-COMM> (141,482)
<COMMON-STOCK-DIVIDENDS> 426,492
<TOTAL-INTEREST-ON-BONDS> 342,471
<CASH-FLOW-OPERATIONS> 1,425,359
<EPS-PRIMARY> (0.50)
<EPS-DILUTED> (0.50)
</TABLE>
<PAGE> 1
[REI - EXHIBIT 99(a)]
[Letterhead of Secretary of State of the State of Texas]
February 2, 1999
RE: HOUSTON INDUSTRIES INCORPORATED
ASSUMED NAME: RELIANT ENERGY, INCORPORATED
FILE DATE: FEBRUARY 2, 1999
The assumed name certificate for the above referenced entity has been filed in
this office. This letter may be used as evidence of the filing.
Please be aware that pursuant to Section 36.17 of the Texas Business and
Commerce Code, the filing of an assumed name certificate does not give the
registrant any right to use the name when contrary to the common law or
statutory law of unfair competition, unfair trade practices, common law
copyright, or similar law.
In addition to filing with the Secretary of State, Chapter 36 of the Texas
Business and Commerce Code requires filing of the assumed name certificate with
the county clerk in the counties in which the registered office and the
principal office are located.
Sincerely yours,
/s/ Lorna Wassdorf
Lorna Wassdorf
Deputy Assistant Secretary
Statutory Filings Division
LSW: pac
<PAGE> 1
[Resources - EXHIBIT 3(a)(3)]
State of Delaware
Office of the Secretary of State PAGE 1
I, EDWARD J. FREEL, SECRETARY OF STATE OF THE STATE OF DELAWARE, DO
HEREBY CERTIFY THE ATTACHED IS A TRUE AND CORRECT COPY OF THE CERTIFICATE OF
AMENDMENT OF "NORAM ENERGY CORP.", CHANGING ITS NAME FROM "NORAM ENERGY CORP."
TO "RELIANT ENERGY RESOURCES CORP.", FILED IN THIS OFFICE ON THE SECOND DAY OF
FEBRUARY, A.D. 1999, AT 11:30 O'CLOCK A.M.
A FILED COPY OF THIS CERTIFICATE HAS BEEN FORWARDED TO THE NEW CASTLE
COUNTY RECORDER OF DEEDS.
[seal]
/s/ Edward J. Freel
-----------------------------------
Edward J. Freel, Secretary of State
[seal]
2651891 8100 AUTHENTICATION: 9554255
991041810 DATE: 02-02-99
<PAGE> 2
CERTIFICATE OF AMENDMENT
TO THE
CERTIFICATE OF INCORPORATION
OF
NORAM ENERGY CORP.
NorAm Energy Corp. (the "Corporation"), a corporation organized and
existing under and by virtue of the General Corporation Law of the State of
Delaware (the "DGCL"), hereby adopts this Certificate of Amendment (this
"Certificate of Amendment"), which amends its Certificate of Incorporation, as
described below, and does hereby further certify that:
1. The name of the Corporation is NorAm Energy Corp.
2. The Board of Directors of the Corporation duly adopted a resolution
proposing and declaring advisable the amendment to the Certificate of
Incorporation as described herein, and the Corporation's sole stockholder duly
adopted such amendment, all in accordance with the provisions of Sections 242
and 228 of the DGCL.
3. The amendment to the Certificate of Incorporation effected by this
Certificate of Amendment changes the name of the Corporation to Reliant Energy
Resources Corp.
4. The Certificate of Incorporation is hereby amended by deleting the
text of Article FIRST thereof in its entirety and replacing in lieu thereof the
following:
"FIRST: The name of the Company is Reliant Energy Resources Corp.
(hereinafter the "Company")."
IN WITNESS WHEREOF, the Corporation has caused this certificate to be
executed this 2nd day of February, 1999.
NORAM ENERGY CORP.
By: /s/ Richard B. Dauphin
------------------------------------
Name: Richard B. Dauphin
Title: Assistant Secretary
<PAGE> 1
[RESOURCES -- EXHIBIT 12]
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
1998 1997 1996 1995 1994
----------- ----------- ----------- ---------- ----------
<S> <C> <C> <C> <C> <C>
Income from Continuing Operations $ 93,824 $ 66,722 $ 95,138 $ 65,529 $ 51,291
Income Taxes for Continuing Operations 111,830 55,781 66,352 55,379 34,372
Non-Utility Interest Capitalized
----------- ----------- ----------- ---------- ----------
205,654 122,503 161,490 120,908 85,663
----------- ----------- ----------- ---------- ----------
Fixed Charges:
Interest 111,460 126,912 130,592 155,584 167,384
Amortization of Debt Discount and Expense 509 3,086 3,582 3,483 3,312
Portion of Rents Considered to Represent an
Interest Factor 8,485 7,988 10,083 16,215 11,292
----------- ----------- ----------- ---------- ----------
Total Fixed Charges 120,454 137,986 144,257 175,282 181,988
----------- ----------- ----------- ---------- ----------
Earnings $ 326,108 $ 260,489 $ 305,747 $ 296,190 $ 267,651
=========== =========== =========== ========== ==========
Ratio of Earnings to Fixed Charges 2.71 1.89 2.12 1.69 1.47
=========== =========== =========== ========== ==========
</TABLE>
173
<TABLE> <S> <C>
<ARTICLE> OPUR1
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION AND IS EXPECTED FROM OUR
RESOURCE'S FINANCIAL STATEMENTS AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE
TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<CIK> 0001042773
<NAME> RELIANT ENERGY RESOURCES CORP.
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> DEC-31-1998
<BOOK-VALUE> PRO-FORMA
<TOTAL-NET-UTILITY-PLANT> 1,357,697
<OTHER-PROPERTY-AND-INVEST> 1,468,131
<TOTAL-CURRENT-ASSETS> 1,546,905
<TOTAL-DEFERRED-CHARGES> 2,282,788
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 6,655,521
<COMMON> 1
<CAPITAL-SURPLUS-PAID-IN> 2,447,827
<RETAINED-EARNINGS> 114,671
<TOTAL-COMMON-STOCKHOLDERS-EQ> 2,562,499
0
0
<LONG-TERM-DEBT-NET> 1,514,446
<SHORT-TERM-NOTES> 0
<LONG-TERM-NOTES-PAYABLE> 300,000
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 203,438
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 2,075,138
<TOT-CAPITALIZATION-AND-LIAB> 6,655,521
<GROSS-OPERATING-REVENUE> 6,758,412
<INCOME-TAX-EXPENSE> 111,830
<OTHER-OPERATING-EXPENSES> 6,448,107
<TOTAL-OPERATING-EXPENSES> 6,448,107
<OPERATING-INCOME-LOSS> 310,305
<OTHER-INCOME-NET> 7,318
<INCOME-BEFORE-INTEREST-EXPEN> 317,623
<TOTAL-INTEREST-EXPENSE> 111,969
<NET-INCOME> 93,824
0
<EARNINGS-AVAILABLE-FOR-COMM> 93,824
<COMMON-STOCK-DIVIDENDS> 0
<TOTAL-INTEREST-ON-BONDS> 111,337
<CASH-FLOW-OPERATIONS> 105,259
<EPS-PRIMARY> 0
<EPS-DILUTED> 0
</TABLE>
