1
================================================================================
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, 1999
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
RELIANT ENERGY, INCORPORATED
(Exact name of registrant as specified in its charter)
TEXAS 74-0694415
(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)
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED
Common Stock, without par value, New York Stock Exchange
and associated rights to purchase preference stock Chicago Stock Exchange
7% Automatic Common Exchange Securities due July 1, 2000 New York Stock Exchange
HL&P Capital Trust I 8.125% Trust Preferred Securities, Series A New York Stock Exchange
REI Trust I 7.20% Trust Originated Preferred Securities, Series C New York Stock Exchange
2.0% Zero-Premium Exchangeable Subordinated Notes due 2027 New York Stock Exchange
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.
(Exact name of registrant as specified in its charter)
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)
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED
NorAm Financing I 6 1/4% Convertible Trust New York Stock Exchange
Originated Preferred Securities
6% Convertible Subordinated Debentures due 2012 New York Stock Exchange
2
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
Reliant Energy, Incorporated (Company) was $6,172,912,484 as of March 10, 2000,
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 10, 2000, the Company had
293,355,835 shares of Common Stock outstanding, including 10,581,513 ESOP shares
not deemed outstanding for financial statement purposes. Excluded from the
number of shares of Common Stock outstanding are 4,808,418 shares held by the
Company as treasury stock. As of March 10, 2000, 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 2000 Annual
Meeting of Shareholders of the Company, which will be filed with the Securities
and Exchange Commission within 120 days of December 31, 1999, are incorporated
by reference in Item 10, Item 11, Item 12 and Item 13 of Part III of this Form
10-K.
================================================================================
3
THIS COMBINED ANNUAL REPORT ON FORM 10-K IS SEPARATELY FILED BY RELIANT
ENERGY, INCORPORATED AND RELIANT ENERGY RESOURCES 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, OR ANY OTHER AFFILIATE OR
SUBSIDIARY OF RELIANT ENERGY, INCORPORATED.
TABLE OF CONTENTS
PART I
Item 1. Business.............................................................................................4
Item 2. Properties..........................................................................................24
Item 3. Legal Proceedings...................................................................................26
Item 4. Submission of Matters to a Vote of Security Holders.................................................26
PART II
Item 5. Market for the Company's Common Equity and Related Stockholder Matters..............................27
Item 6. Selected Financial Data of the Company..............................................................28
Company
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations of the
Company.............................................................................................30
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 its Consolidated Subsidiaries..................................................................106
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.........................................110
Item 8. Financial Statements and Supplementary Data of Resources...........................................111
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure...............141
PART III
Item 10. Directors and Executive Officers of Reliant Energy and Resources Corp..............................141
Item 11. Executive Compensation.............................................................................141
Item 12. Security Ownership of Certain Beneficial Owners and Management.....................................141
Item 13. Certain Relationships and Related Transactions.....................................................142
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K....................................143
1
4
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
From time to time, Reliant Energy, Incorporated (Reliant Energy) and
Reliant Energy Resources Corp. (Resources Corp.) make statements concerning
their respective expectations, beliefs, plans, objectives, goals, strategies,
future events or performance and underlying assumptions and other statements
which are not historical facts. These statements are "forward-looking
statements" within the meaning of the Private Securities Litigation Reform Act
of 1995. Although Reliant Energy and Resources Corp. believe that the
expectations and the underlying assumptions reflected in their respective
forward-looking statements are reasonable, they cannot assure you that these
expectations will prove to be correct. Forward-looking statements involve a
number of risks and uncertainties, and actual results may differ materially from
the results discussed in the forward-looking statements.
The following are among the important factors that could cause actual
results to differ materially from the forward-looking statements:
o state and federal legislative or regulatory developments
o national or regional economic conditions
o industrial, commercial and residential growth in service
territories of Reliant Energy, Resources Corp. and their
subsidiaries
o the timing and extent of changes in commodity prices and
interest rates
o weather variations and other natural phenomena
o growth in opportunities for Reliant Energy's and Resources
Corp.'s diversified operations
o the results of financing efforts
o the ability to consummate and timing of consummation of pending
acquisitions and dispositions
o the speed, degree and effect of continued electric industry
restructuring in North America and Western Europe, and
o risks incidental to Reliant Energy's, Resources Corp.'s and
their subsidiaries' overseas operations, including the effects
of fluctuations in foreign currency exchange rates
For a discussion of some additional factors that could cause actual results
to differ materially from those expressed or implied in forward-looking
statements, see "Management's Discussion and Analysis of Financial Condition and
Results of Operations of the Company -- Certain Factors Affecting Future
Earnings of the Company." Any forward-looking statements should be considered in
light of these important factors and in conjunction with the other documents
filed by Reliant Energy and Resources Corp. with the SEC.
New factors that could cause actual results to differ materially from those
described in forward-looking statements may emerge from time to time. It is not
possible for Reliant Energy or Resources Corp. to predict all of these factors,
or the extent to which any factor or combination of factors may cause actual
results to differ from those contained in any forward-looking statement. Any
forward-looking statement speaks only as of the date on which the statement is
made and neither Reliant Energy nor Resources Corp. undertakes any obligation to
update the information contained in the statement to reflect subsequent
developments or information.
2
5
The following sections of this Form 10-K contain forward-looking statements
which you can identify by the words "anticipate," "estimate," "expect,"
"forecast," "goal," "objective," "projection" or other similar words:
o Business--
o Electric Operations--
Deregulation and Competition
Electric Operations Assets
Fuel
o Wholesale Energy --
Power Generation
Wholesale Energy Trading, Marketing and Risk Management
o Reliant Energy Europe --
UNA
European Energy Trading and Marketing
o Environmental Matters
o Legal Proceedings
o Management's Discussion and Analysis of Financial Condition and Results
of Operations of the Company --
o Results of Operation by Business Segment --
Wholesale Energy
Reliant Energy Europe
Reliant Energy Latin America
o Certain Factors Affecting Future Earnings of the Company--
Competition and Restructuring of the Texas Electric Utility
Industry
Competition - Reliant Energy Europe Operations
Competition - Other Operations
Impact of the Year 2000 Issue and Other System
Implementation Issues
Entry into the European Market
Risk of Operations in Emerging Markets
Environmental Expenditures
o Liquidity and Capital Resources--
Company Consolidated Capital Requirements
Future Sources and Uses of Cash Flows
o New Accounting Issues
o Quantitative and Qualitative Disclosures About Market Risk
3
6
PART I
ITEM 1. BUSINESS.
GENERAL
Reliant Energy, Incorporated (Reliant Energy) is a Texas corporation
incorporated in 1906. Reliant Energy Resources Corp. (Resources Corp.) is a
Delaware corporation incorporated in 1996. The term "Company" is used in this
Form 10-K to refer collectively to Reliant Energy and its subsidiaries,
including Resources Corp. The term "Resources" is used in this Form 10-K to
refer collectively to Resources Corp. and its subsidiaries. The executive
offices of Reliant Energy and Resources Corp. are located at 1111 Louisiana,
Houston, TX 77002 (telephone number 713-207-3000). Prior to February 1999,
Reliant Energy conducted business under the name "Houston Industries
Incorporated" and Resources Corp. conducted business under the name "NorAm
Energy Corp."
The Company is a diversified international energy services company that
provides energy and energy services in North America, Western Europe and Latin
America through the following business segments:
o Electric Operations
o Natural Gas Distribution
o Interstate Pipelines
o Wholesale Energy
o Reliant Energy Europe
o Reliant Energy Latin America, and
o Corporate
For information about the revenues, operating income, assets and other
financial information relating to the Company's business segments, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company--Results of Operations by Business Segment," Note 18
to the Company's Consolidated Financial Statements, "Management's Narrative
Analysis of the Results of Operations of Reliant Energy Resources Corp. and its
Consolidated Subsidiaries" and Note 9 to Resources Corp.'s Consolidated
Financial Statements.
Resources is a domestic natural gas utility, an interstate natural gas
pipeline company and a provider of energy marketing services. Resources'
operations are described below in the consolidated description of the Company's
business segments.
ELECTRIC OPERATIONS
Electric Operations conducts operations under the name "Reliant Energy
HL&P," an unincorporated division of Reliant Energy. Electric Operations
generates, purchases, transmits and distributes electricity to approximately 1.7
million customers in a 5,000 square mile area on the Texas Gulf Coast, including
Houston, Texas, the nation's fourth largest city.
SERVICE AREA
Houston's economy, although it has become increasingly diversified over the
past ten years, is still focused 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, 1999, energy sector industries accounted for
approximately 32% of Electric Operations' industrial electric base revenues and
4
7
7% 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.
Reliant Energy 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.
DEREGULATION AND COMPETITION
In June 1999, the Texas legislature adopted the Texas Electric Choice Plan
(Legislation). The Legislation substantially amends the regulatory structure
governing electric utilities in Texas in order to allow retail competition
beginning January 1, 2002. In preparation for competition, the Company expects
to make significant changes in the electric utility operations it conducts
through Reliant Energy HL&P. Under the Legislation:
o beginning on January 1, 2002, most retail customers of
investor-owned electric utilities in Texas, including Reliant
Energy HL&P, will be entitled to purchase their electricity from
any of a number of "retail electric providers" which will have
been certified by the Public Utility Commission of Texas (Texas
Utility Commission)
o power generators will sell electric energy to wholesale
purchasers, including retail electric providers, at unregulated
rates beginning January 1, 2002
o by January 1, 2002, electric utilities in Texas, including Reliant
Energy HL&P, will have restructured their businesses in order to
separate power generation, transmission and distribution and
retail electric provider activities into different units
As required by the Legislation, the Company submitted a plan in January
2000 to accomplish the separation of its regulated operations into separate
units and is currently awaiting approval from the Texas Utility Commission. For
further information regarding the Legislation and its application to Reliant
Energy HL&P's operations and structure, see "Management's Discussion and
Analysis of Financial Condition and Results of Operations of the
Company--Certain Factors Affecting Future Earnings of the Company--Competition
and Restructuring of the Texas Electric Utility Industry" and Note 3 to the
Company's Consolidated Financial Statements, which Section and Note are
incorporated herein by reference.
ELECTRIC OPERATIONS ASSETS
As of December 31, 1999, Reliant Energy HL&P owned and operated 12 electric
generating stations (62 generating units), with a combined turbine nameplate
rating of 13,554,608 kilowatts (KW), and 215 major substation sites (242
substations) having a total installed rated transformer capacity of 54,763
megavolt amperes (Mva). Reliant Energy HL&P owns a 30.8% interest in the South
Texas Project Electric Generating Station (South Texas Project), a nuclear
generating plant with two 1,250 megawatt (MW) nuclear generating units.
5
8
The following table contains information regarding Electric Operations'
system capability:
INSTALLED FIRM
NET PURCHASED CALCULATED
CAPABILITY POWER TOTAL NET MAXIMUM HOURLY FIRM % CHANGE RESERVE
AT PEAK CONTRACTS CAPABILITY DEMAND FROM MARGIN
YEAR (MW) (MW) (MW) DATE MW(1)(2) PRIOR YEAR (%)
------------------- ---------- ---------- ---------- ------- --------- ---------- ----------
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
1999............... 14,052 320 14,372 Aug. 20 13,215 1.6 8.8
- ----------
(1) 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 1999 was 14,642 MW
compared to 14,272 MW in 1998 and 13,459 MW in 1997.
(2) Maximum hourly firm demand in 1999 and 1998 were influenced by warmer than
normal weather at the time of the system peak.
Based on present trends, Reliant Energy estimates that the maximum hourly
firm demand for electricity in Reliant Energy HL&P's service area will grow at a
compound annual rate of approximately 1.5% over the next ten years. Assuming
average weather conditions and including the net effects of demand-side
management programs, Reliant Energy expects that Electric Operations' reserve
margin in excess of maximum hourly firm demand load requirements will be 15% in
2000 and 2001. The reduced reserve margins for 1999 and 1998 reflect the
extremely hot weather conditions in Electric Operations' service area during
those summers, which increased system peak loads by approximately 500 MW and 400
MW, respectively.
Electric Operations' sales of electricity during the summer months are
generally higher, and can be significantly higher, than sales during other
months of the year due to the reliance on air conditioning by customers in
Reliant Energy HL&P's service territory.
CAPITAL EXPENDITURES
For information about Electric Operations' capital expenditures, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Liquidity and Capital Resources -- Company
Consolidated Capital Requirements."
FUEL
Electric Operations relies primarily on natural gas, coal and lignite for
the generation of electricity. Electric Operations' 1999 and 1998 historical
energy mix is set forth below. These figures represent Reliant Energy HL&P
generation and purchased power used to meet system load and for off-system
sales.
HISTORICAL ENERGY MIX (%)
-------------------------
1999 1998
---- ----
Natural gas ............ 35 33
Coal and lignite ....... 39 38
Nuclear ................ 8 8
Purchased power ........ 18 21
---- ----
Total ........ 100 100
==== ====
6
9
Reliant Energy HL&P's energy mix is not expected to vary materially during
the years 2000 and 2001 based on current assumptions regarding the cost and
availability of fuel, plant operation schedules, load growth, load management
and the impact of environmental regulations. Reliant Energy HL&P's energy mix
after the year 2001 could change materially as a result of the Legislation and
the advent of retail electric competition in 2002.
Natural Gas Supply. In 1999, Electric Operations purchased approximately
50% of its natural gas requirements under long-term contracts which will expire
in 2004. The largest supplier under such contracts is Midcon Texas Pipeline
Corporation, a unit of KN Energy, Inc. (comprising 28% of its natural gas
requirements). Electric Operations purchased the remaining 50% 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 current market conditions, Reliant Energy believes it
will be able to replace the supplies of natural gas covered under expiring
long-term contracts with gas purchased on the spot market or under long-term or
short-term contracts. Electric Operations' 1999 natural gas consumption and cost
information are as follows:
1999 average daily consumption 728 Bbtu
1999 peak daily consumption 1,656 Bbtu
Average cost of natural gas $ 2.47 per MMBtu (1)
- ---------
(1) Compared to $2.18 per MMBtu in 1998 and $2.60 per MMBtu in 1997.
Although natural gas supplies have been sufficient 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.
Coal and Lignite Supply. Electric Operations purchases approximately 80% of
the coal for its four coal-fired units under two long-term contracts from mines
in Wyoming. The first of these contracts will expire in 2010, and the second
will expire in 2011. Electric Operations obtains the remaining coal required to
operate these units under short-term contracts. Burlington Northern Santa Fe
Railroad transported the majority of Electric Operations' coal supply during
1999 under a rail transportation contract. A new long-term rail transportation
contract with Burlington Northern Santa Fe Railroad went into effect in March
2000. Union Pacific Railroad Company also transported a portion of Electric
Operations' coal supply during 1999.
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. Reliant Energy owns the mining equipment, facilities and a portion
of the lignite reserves located at this mine. Reliant Energy believes the
lignite reserves the Company currently owns under lease and contract will be
sufficient to provide substantially all of the lignite requirements of Limestone
through 2015.
Nuclear Fuel Supply. The South Texas Project satisfies its fuel supply
requirements by:
o acquiring uranium concentrates
o converting uranium concentrates into uranium hexafluoride
o enriching uranium hexafluoride, and
o fabricating nuclear fuel assemblies
7
10
The South Texas Project has contracted for the raw materials and services
necessary to operate the plant through the following years, respectively:
Raw material/services Year
- --------------------- --------
Uranium................................................. 2002 (1)
Conversion.............................................. 2002 (2)
Enrichment.............................................. 2004 (3)
Fabrication............................................. 2005
- ----------
(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 spot market and medium-term contracts.
(2) Contracts provide for up to 80% of the conversion needs through 2002 and up
to 40% of conversion needs through 2004. The South Texas Project expects to
obtain the balance of the conversion needs through the spot market.
(3) Contracts provide for up to 100% of enrichment services through 2001, up to
75% of enrichment services through 2003 and up to 40% of enrichment
services through 2004. The South Texas Project expects to obtain the
balance of enrichment services through spot market and medium and long-term
contracts.
Purchased Power Supply. 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.
8
11
OPERATING STATISTICS OF ELECTRIC OPERATIONS
YEAR ENDED DECEMBER 31,
--------------------------------------------
1999 1998 1997
------------ ------------ ------------
Electric Energy Generated and Purchased (Megawatt-Hours (MWH)):
Generated-- Net Station Output .................................. 60,496,310 59,974,160 56,066,845
Purchased ....................................................... 14,788,411 16,041,143 14,008,452
Net Interchange ................................................. 1,131 (677) 841
------------ ------------ ------------
Total .................................................... 75,285,852 76,014,626 70,076,138
Company Use, Lost and Unaccounted for Energy .................... (3,167,192) (3,281,851) (2,998,375)
------------ ------------ ------------
Total Energy Sold ........................................ 72,118,660 72,732,775 67,077,763
Electric Sales (MWH):
Residential ..................................................... 21,109,374 21,090,164 19,365,892
Commercial ...................................................... 16,671,917 16,329,354 15,474,761
Small Industrial(1) ............................................. 11,757,318 11,801,292 11,439,753
Large Industrial(1) ............................................. 14,427,128 14,805,199 14,380,499
Street Lighting-- Government and Municipal ...................... 138,311 133,644 127,761
------------ ------------ ------------
Total Firm Retail Sales .................................. 64,104,048 64,159,653 60,788,666
Other Electric Utilities ........................................ 224,849 203,542 190,878
------------ ------------ ------------
Total Firm Sales ......................................... 64,328,897 64,363,195 60,979,544
Interruptible ................................................... 5,309,656 5,028,990 4,278,458
Off-System and Ancillary ........................................ 2,519,260 3,137,870 1,742,993
Unbilled ........................................................ (39,153) 202,720 76,768
------------ ------------ ------------
Total .................................................... 72,118,660 72,732,775 67,077,763
============ ============ ============
Number of Customers (End of Period):
Residential ..................................................... 1,463,210 1,417,206 1,378,658
Commercial ...................................................... 203,322 196,941 190,437
Small Industrial(1) ............................................. 1,642 1,600 1,526
Large Industrial (Including Interruptible)(1) ................... 146 137 132
Street Lighting-- Government and Municipal ...................... 89 87 86
Other Electric Utilities (Including Off-System) ................. 23 29 20
------------ ------------ ------------
Total .................................................... 1,668,432 1,616,000 1,570,859
============ ============ ============
Operating Revenue (Thousands of Dollars):
Residential ..................................................... $ 1,773,925 $ 1,786,662 $ 1,662,177
Commercial ...................................................... 1,146,185 1,108,328 1,065,917
Small Industrial(1) ............................................. 642,857 637,124 616,419
Large Industrial(1) ............................................. 528,197 534,814 529,718
Street Lighting-- Government and Municipal ...................... 27,261 25,964 24,868
------------ ------------ ------------
Total Electric Revenue-- Firm Retail Sales ............... 4,118,425 4,092,892 3,899,099
Other Electric Utilities ........................................ 11,383 12,609 11,330
------------ ------------ ------------
Total Electric Revenue-- Firm Sales ...................... 4,129,808 4,105,501 3,910,429
Interruptible ................................................... 128,844 114,574 108,053
Off-System/Ancillary ............................................ 72,608 87,510 39,724
------------ ------------ ------------
Total Electric Revenue ................................... 4,331,260 4,307,585 4,058,206
Miscellaneous Electric Revenues (including Unbilled Revenues) ... 151,866 42,690 193,037
------------ ------------ ------------
Total .................................................... $ 4,483,126 $ 4,350,275 $ 4,251,243
============ ============ ============
Installed Net Generating Capability (KW) (End of Period) .......... 14,217,370 14,092,370 14,040,370
Cost of Fuel (Cents per MMBtu):
Gas ............................................................. 246.7 218.4 259.9
Coal ............................................................ 176.1 177.8 201.8
Lignite ......................................................... 142.3 119.1 108.4
Nuclear ......................................................... 43.5 48.0 54.2
Average .................................................. 186.9 169.9 186.8
- ----------
(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.
9
12
NATURAL GAS DISTRIBUTION
Natural Gas Distribution conducts operations through three divisions of
Resources Corp., Reliant Energy Arkla (Arkla), Reliant Energy Entex (Entex) and
Reliant Energy Minnegasco (Minnegasco). Natural Gas Distribution's operations
consist of intrastate natural gas sales to, and natural gas transportation for,
residential, commercial and industrial customers in Arkansas, Louisiana,
Minnesota, Mississippi, Oklahoma and Texas. The operations of Natural Gas
Distribution are regulated as gas utility operations in the jurisdictions served
by these divisions.
The Company has retained a financial adviser to assist it in evaluating
strategic alternatives for Arkla and Minnegasco, including divestiture.
Arkla. Arkla provides natural gas distribution services in Arkansas,
Louisiana, Oklahoma and Texas. The largest metropolitan areas served by Arkla
are Little Rock, Arkansas and Shreveport, Louisiana. In 1999, approximately 67%
of Arkla's total throughput was attributable to retail sales of gas and
approximately 33% was attributable to transportation services. Sales to
residential and commercial customers in 1999 accounted for approximately 92% of
Arkla's total gas revenues and 60% of natural gas volumes sold or transported by
Arkla.
Entex. Entex provides natural gas distribution services in 502 communities
in Louisiana, Mississippi and Texas. The largest metropolitan area served by
Entex is Houston, Texas. In 1999, approximately 97% of Entex's total throughput
was attributable to retail sales of gas and approximately 3% was attributable to
transportation services. Sales to residential and commercial customers in 1999
accounted for approximately 85% of Entex's total gas revenues and 79% of natural
gas volumes sold or transported by Entex.
Minnegasco. Minnegasco provides natural gas distribution services in 243
communities in Minnesota. The largest metropolitan area served by Minnegasco is
Minneapolis, Minnesota. In 1999, approximately 97% of Minnegasco's total
throughput was attributable to retail sales of gas and approximately 3% was
attributable to transportation services. Sales to residential and commercial
customers in 1999 accounted for approximately 93% of Minnegasco's total gas
revenues and 84% of natural gas volumes sold or transported by Minnegasco.
The demand for natural gas distribution services is seasonal. In 1999,
approximately 67% 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
Arkla. In 1999, Arkla purchased approximately 40% of its natural gas supply
from Reliant Energy Services, Inc. (Reliant Energy Services), a subsidiary of
Resources Corp., 32% pursuant to third party contracts, with terms varying from
three months to one year, and 28% on the spot market. Arkla's major third party
natural gas suppliers in 1999 included Seagull Marketing Services, Inc.,
Marathon Oil Company, Cinergy Marketing and Trading, LLC, Aquila Energy
Marketing Corporation, PG&E Energy Trading - Gas Corporation and Oneok Gas
Marketing Company. Arkla transports substantially all of its natural gas
supplies under contracts with the Company's interstate pipeline subsidiaries.
These contracts will expire in March 2002.
Entex. In 1999, Entex purchased approximately 99% of its natural gas supply
pursuant to term contracts, with terms varying from one to five years, and 1% on
the spot market. Entex's major third party natural gas suppliers in 1999 were
Gulf Energy Marketing, Koch Energy Trading, Midcon Texas Pipeline Corporation, a
unit of KN Energy, Inc., and Enron North America Company. Entex transports its
natural gas supplies on both interstate and intrastate pipelines under long-term
contracts with terms varying from one to five years.
Minnegasco. In 1999, Minnegasco purchased approximately 70% of its natural
gas supply pursuant to term contracts, with terms varying from one to ten years,
with more than 30 different suppliers. Minnegasco purchased the remaining 30% on
the spot market. Most of the natural gas volumes under long-term contracts are
committed under
10
13
terms providing for delivery during the winter heating season, November through
March. Minnegasco purchased approximately 58% of its natural gas requirements
from the following four suppliers in 1999: Pan-Alberta Gas Ltd., TransCanada Gas
Services Inc., Duke Energy Trading and Marketing, LLC and Reliant Energy
Services. Minnegasco transports its natural gas supplies on various interstate
pipelines under long-term contracts with terms varying from five to ten years.
Arkla and Minnegasco use various leased or owned natural gas storage
facilities to meet peak-day requirements and to manage the daily changes in
demand due to changes in weather. Minnegasco also supplements contracted
supplies and storage from time to time with stored liquefied natural gas and
propane-air plant production.
Although natural gas supplies have been sufficient 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
Interstate Pipelines provides interstate gas transportation and related
services through two wholly owned subsidiaries of Resources Corp.: (i) Reliant
Energy Gas Transmission Company (REGT) and (ii) Mississippi River Transmission
Corporation (MRT).
Interstate Pipelines owns and operates approximately 8,200 miles of
transmission lines and six natural gas storage facilities located across the
south-central United States. Interstate Pipelines stores, transports and
delivers natural gas on behalf of various shippers primarily to utilities,
industrial customers and third party pipeline interconnectors. Interstate
Pipelines also provides pipeline project management and facility operation
services to affiliates and third parties.
The Company has retained a financial adviser to assist it in evaluating
strategic alternatives for REGT and MRT, including divestiture.
In 1999, approximately 40% of Interstate Pipelines' total operating revenue
was attributable to services provided by REGT to Arkla and approximately 16% 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 15% of Interstate Pipelines' operating
revenues was attributable to the transportation of gas marketed by Reliant
Energy Services. Interstate Pipelines provides service to Arkla and Laclede
under several long-term firm storage and transportation agreements. The
expiration dates for the service agreements with Laclede range from October 2000
through May 2001. Interstate Pipelines and Laclede are currently negotiating the
terms and conditions of a proposed renewal of these agreements. The service
agreement with Arkla is scheduled to expire in March 2002.
The business and operations of Interstate Pipelines may be 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.
WHOLESALE ENERGY
Wholesale Energy conducts its operations through: (i) Reliant Energy Power
Generation, Inc. (collectively with its subsidiaries, Power Generation), a
subsidiary of Reliant Energy, (ii) Reliant Energy Services and (iii) Reliant
Energy Field Services, Inc. (Reliant Energy Field Services), a wholly owned
subsidiary of Resources Corp.
11
14
Wholesale Energy's operations include:
o the acquisition, development and operation of domestic unregulated
power generation facilities
o sales of capacity, energy and ancillary services from domestic
unregulated power generation facilities
o wholesale energy trading, marketing and risk management services
in North America, and
o domestic natural gas gathering activities
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,
Wholesale Energy's trading and marketing unit, supplies fuel to these generating
plants and sells electricity produced by the plants. In 1999, Power Generation
generated and Reliant Energy Services sold, approximately 6.1 million MWHs of
electricity. Substantially all of these sales were in the California
marketplace.
Power Generation Projects. Power Generation owns fifteen electric
generating units at five sites (3,800 MW in the aggregate) located in southern
California. Reliant Energy Services serves as the plants' exclusive power
marketer and supplier of natural gas. Power Generation was required under the
agreements for the acquisition of these plants to enter into contracts with
Southern California Edison Company, the former owner, to operate and maintain
the plants through April and July 2000. These contracts have been renegotiated
and renewed through March 2003. Power Generation does, however, exercise
management authority over the plants' operations. For information on regulation
of these units, see "Regulation - Federal Energy Regulatory Commission (FERC)"
below.
On October 6, 1999, Power Generation purchased the Indian River power
plant located near Titusville, Florida from the Orlando Utilities Commission
(OUC) for approximately $205 million. The Indian River power plant consists of
three conventional steam generation units fueled by both oil and natural gas.
The 619-megawatt generation station will continue to provide power to OUC under
a four-year power purchase agreement. Excess power generated by the plant will
be sold to the wholesale market, other utilities and rural electric cooperatives
within the area.
In December 1999, Power Generation's Sabine Cogeneration Project commenced
commercial operations. The Sabine Cogeneration Project is located in Orange,
Texas and consists of a 100 MW gas-fired cogeneration plant. Power Generation
has a 50% ownership interest in the project.
Power Generation has the following projects under construction or in
startup and testing phases:
PROJECT LOCATION INTEREST PROJECTED COMPLETION DATE
- ------------------------------------- ------------- -------- -------------------------
El Dorado Boulder City, 50% Second Quarter of 2000
(490 MW gas-fired merchant plant) Nevada
Desert Basin Casa Grande, 100% Third Quarter of 2001
(560 MW gas-fired merchant plant) Arizona
Channelview Texas Project Channelview, 100% Third Quarter of 2002
(780 MW gas-fired cogeneration plant) Texas
12
15
In 1998 and 1999, Power Generation announced plans for the development of
several power projects which are not yet under construction. These projects have
a combined capacity of 1,800 MW and are located in Illinois, Rhode Island and
Florida. Negotiation of development contracts regarding these projects is
underway and each of these projects has obtained various construction permits
and zoning approvals and are expected to be under construction during the second
and third quarters of 2000.
In February 2000, Power Generation signed a definitive agreement to
purchase from Sithe Energies, Inc. non-rate regulated power generating assets
and sites located in Pennsylvania, New Jersey and Maryland, having a net
generating capacity of more than 4,200 MW for an aggregate purchase price of
$2.1 billion, subject to certain adjustments. The acquisition is expected to
close in the second quarter of 2000 subject to obtaining certain regulatory
approvals and satisfying other closing conditions. The acquisition will be
accounted for as a purchase.
Reliant Energy expects Power Generation will continue to acquire and
develop non-rate regulated power projects. 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 could finance a portion of its non-rate regulated
power projects through the proceeds from project financings, lease agreements,
borrowings by subsidiaries or equity investments and loans from Reliant Energy
and financing subsidiaries of Reliant Energy.
The successful completion of other non-rate regulated power projects is
dependent upon a number of factors, which include:
o risks associated with siting, financing, construction and permitting
o the degree of success in obtaining governmental approvals
o the development of power markets
o the risk of termination of power sales contracts, if any, as a
result of a failure to meet certain construction milestones, and
o the uncertainties arising from the changing regulatory systems
affecting Power Generation's markets
Many of the facilities being acquired or developed by Power Generation are
"merchant plants," that is, plants lacking dedicated offtake customers, making
such facilities sensitive to market and regulatory factors and other
considerations.
For a description of the competitive conditions affecting Wholesale
Energy, see "Management's Discussion and Analysis of Financial Condition and
Results of Operations - Certain Factors Affecting Future Earnings of the
Company - Competition - Other Operations," which section is incorporated herein
by reference.
WHOLESALE ENERGY TRADING, MARKETING AND RISK MANAGEMENT
Reliant Energy Services buys, sells and trades natural gas, electric power,
crude oil and refined products, certain air emissions regulatory credits, coal
and weather derivatives. In addition, it offers physical and financial wholesale
energy marketing and price risk management products and services to a variety of
customers. These customers include natural gas distribution companies, electric
utilities, municipalities, cooperatives, power generators, marketers,
aggregators and large volume industrial customers.
Natural Gas. Reliant Energy Services purchases natural gas from a variety
of suppliers under daily, monthly, variable load, base load and term contracts
that include either market sensitive or fixed pricing provisions. It 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. Reliant
Energy Services sold 5.0 billion cubic feet (BCF) per day and 3.2 BCF per day of
natural gas in 1999 and 1998, respectively, most of which was sold to
non-affiliates.
13
16
Reliant Energy Services' natural gas marketing activities include
contracting to buy natural gas from suppliers at various points of receipt,
aggregating natural gas supplies and arranging for their transportation,
negotiating the sale of natural gas, 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. 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 its customers.
Electric Power. Reliant Energy Services sells electric power primarily to
electric utilities, municipalities and cooperatives and other marketing
companies. Reliant Energy Services sold over 112 million MWHs and 65 million
MWHs of electric power in 1999 and 1998, respectively. Reliant Energy Services
plans to continue to supply natural gas to, and purchase electricity for resale
from, non-rate regulated power plants in deregulated markets, including
generating plants currently owned or to be developed, acquired or operated by
Power Generation.
Crude Oil. Reliant Energy Services buys and sells crude oil and other
hydrocarbon products. Reliant Energy Services sold 8.6 million barrels of these
products primarily to end-use customers and other marketing companies in 1999.
Other Commodities and Weather Derivatives. Reliant Energy Services trades
and markets certain air emissions regulatory credits, coal and weather
derivatives.
Reliant Energy Services uses derivative financial instruments to:
o manage and hedge its fixed-price purchase and sale commitments
o provide fixed-price or floating-price commitments as a service to
its customers and suppliers
o reduce its exposure relative to the volatility of the cash market
prices, and
o protect its investment in storage inventories
In 1999, Reliant Energy Services financially settled on average over 25
trillion British thermal units equivalents (Tbtue) per day of energy derivative
financial instruments in its trading and price risk management activities,
compared to an average of over 11 Tbtue per day in 1998. Reliant Energy Services
is exposed in such transactions to the risk that fluctuating market prices may
adversely affect the Company's financial position or results of operations. For
additional information with respect to the Company's financial exposure to
derivative financial instruments, see Item 7A of this Form 10-K, Note 5 to the
Company's Consolidated Financial Statements and Note 2 to Resources Corp.'s
Consolidated Financial Statements.
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. The Company
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 5 to the Company's Consolidated Financial Statements and
Note 2 to Resources Corp.'s Consolidated Financial Statements.
14
17
Reliant Energy has established a Risk Oversight Committee, comprised of
corporate and business segment officers, that oversees all commodity price and
credit risks activities, including trading, marketing and risk management
activities of Wholesale Energy and Reliant Energy Europe. For additional
information regarding risk management accounting policies, see Note 5 to the
Company's Consolidated Financial Statements and Note 2 to Resources Corp.'s
Consolidated Financial Statements.
NATURAL GAS GATHERING
Reliant Energy Field Services provides natural gas gathering services,
including related liquids extraction and marketing activities. Reliant Energy
Field Services operates approximately 4,000 miles of gathering pipelines which
collect natural gas from more than 200 separate systems located in major
producing fields in Arkansas, Louisiana, Oklahoma and Texas.
The Company has retained a financial adviser to assist it in evaluating
strategic alternatives for Reliant Energy Field Services, including divestiture.
RELIANT ENERGY EUROPE
The Company established its Reliant Energy Europe business segment in the
fourth quarter of 1999. Reliant Energy Europe owns, operates and sells electric
power from generation facilities in the Netherlands and plans to participate in
the emerging wholesale energy trading and marketing industry in the Netherlands
and other countries in Europe.
UNA
During 1999, the Company completed the first two phases of its acquisition
of N.V. UNA (UNA), a Dutch power generation company. The Company acquired 40%
and 12% of UNA's capital stock on October 7, 1999 and December 1, 1999,
respectively. On March 1, 2000, the Company purchased the remaining 48% of the
shares of UNA. The total purchase price of the acquisition is approximately $2.4
billion (based on an exchange rate of 2.0565 Dutch guilders (NLG) per U.S.
dollar as of October 7, 1999), which includes a $426 million promissory note to
UNA. For additional information about this acquisition, including the Company's
accounting treatment of the acquisition, see Note 2 to the Company's
Consolidated Financial Statements.
UNA is one of the Netherlands' four largest generating companies and is the
first Dutch generating company whose stock was sold to private investors under a
privatization program established under the Dutch Electricity Act. In 1999, UNA
generated more than 20% of the country's electricity production, excluding
electricity generated by cogeneration or other industrial processes. UNA serves
the provinces of North-Holland and Utrecht, as well as the municipalities of
Amsterdam and Utrecht, providing electricity for approximately two million
people and more than 12,000 commercial users. As of December 31, 1999, UNA owned
and operated 14 generating stations with 3,472 MW of capacity spread across five
sites. UNA's generating stations also supply several large municipalities with
hot water for district heating purposes. In 1999, approximately 47% of UNA's
generation output was natural gas fired, 19% was blast furnace fired and 34% was
coal fired.
In 1999, UNA and the three other largest Dutch generators supplied
approximately 60% of the electricity consumed in the Netherlands. Smaller Dutch
producers supplied about 28% of such consumed electricity and the remainder was
imported. The Dutch electricity market is expected to be gradually opened for
wholesale competition including certain commercial and industrial customers
beginning in 2001. Competition is expected to increase in subsequent years and
it is anticipated that the market for small businesses and residential customers
will become open to competition by 2007. The timing of the opening of these
markets is subject, however, to change at the discretion of the Minister of
Economic Affairs.
The markets and regulatory scheme in which UNA operates and the pending
changes therein are described in "Management's Discussion and Analysis of
Financial Condition and Results of Operations of the Company --Results of
Operations by Business Segment -- Reliant Energy Europe," "-- Certain Factors
Affecting Future Earnings
15
18
of the Company -- Competition -- Reliant Energy Europe Operations" and "-- Entry
into the European Market," which descriptions are incorporated herein by
reference.
EUROPEAN ENERGY TRADING AND MARKETING
In October 1999, Reliant Energy formed Reliant Energy Trading & Marketing
B.V., a Dutch corporation (Reliant Energy Marketing Europe), in order to
participate in the emerging European energy trading and marketing businesses.
Reliant Energy Marketing Europe initially will focus on trading opportunities in
the Netherlands and expand into other European markets. Reliant Energy Europe
intends to trade in derivative products, including forwards, swaps, options and
futures. Reliant Energy Marketing Europe will initially concentrate on marketing
power to large industrial and commercial customers as well as distribution
companies in the Netherlands and Germany. At March 1, 2000, Reliant Energy
Marketing Europe had approximately 40 employees. Reliant Energy Marketing Europe
is expected to become the main marketer of UNA's electric generation output
beginning in 2001.
RELIANT ENERGY LATIN AMERICA
Reliant Energy Latin America conducts its operations through Reliant Energy
International, Inc. (Reliant Energy International), a wholly owned subsidiary of
Reliant Energy, and the international operations of Resources (Resources
International). Reliant Energy Latin America participates in the privatization
of generation and distribution facilities and independent power projects
primarily in Latin America.
Reliant Energy is evaluating the sale of the Company's Latin American
assets in order to pursue business opportunities that are in line with its
strategies for the U.S. and Western Europe.
For a discussion of risks associated with Reliant Energy Latin America's
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 -- Risk of Operations in Emerging Markets,"
"Quantitative and Qualitative Disclosures About Market Risk -- Foreign Currency
Exchange Rate Risk" in Item 7A of this Form 10-K and Note 7 to the Company's
Consolidated Financial Statements.
MAJOR LATIN AMERICAN INVESTMENTS
Argentina. As of December 31, 1999, approximately 11% of Reliant Energy
Latin America's investments were located in Argentina. The Company currently
owns 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).
Brazil. As of December 31, 1999, approximately 26% of Reliant Energy Latin
America's investments were located in Brazil. The Company indirectly owns 11.78%
of the common stock of Light Servicos de Eletricidade S.A. (Light), a publicly
held Brazilian corporation, 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 Company and the other
winning bidders in the government sponsored auction for Light formed a
consortium whose aggregate ownership interest of 51.35% represents a controlling
interest in Light. Light owns 77.81% 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, 1999, approximately 46% of Reliant Energy
Latin America's investments were located in Colombia. The Company and
Corporacion EDC S.A.C.A. (CEDC), jointly own, through subsidiaries, 65% of the
stock of two Colombian electric distribution companies, Electricaribe and
Electrocosta. These companies serve approximately 1.2 million customers in the
Atlantic coastal region of Colombia, including the cities of Santa Marta,
Barranquilla and Cartagena.
16
19
Additionally, the Company 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. In addition to its
distribution facilities, EPSA owns 850 MW of electric generation capacity. EPSA
also owns an 86.4% interest in Compania de Electricidad de Tulua (CET). 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, 1999, aggregate
expenditures incurred with respect to these concessions were approximately $7
million.
El Salvador. As of December 31, 1999, approximately 15% of Reliant Energy
Latin America's investments were located in El Salvador. Reliant Energy Latin
America holds interests in three electric systems in El Salvador (ranging from
approximately 37% to 45%).
Other. The Company, together with various other investors, developed a coke
calcining and power generation facility in India. The Company's total investment
in this project is approximately $13 million. Resources International and a
local investor sold their interest in a natural gas distribution system in
northeastern Mexico in November 1999 for $8.4 million.
CORPORATE
The Company's Corporate business segment includes:
o the operations of Reliant Energy Retail which conducts retail gas
marketing services
o the operations of Reliant Energy Communications, Inc. (Reliant
Energy Communications) which offers enhanced data, voice and
Internet services to customers in Texas
o the operations of Reliant Energy Solutions, Inc. (Reliant Energy
Solutions) which provides a range of design-build and operational
energy services, including energy system and central plant retrofits
o the operations of Reliant Energy Thermal Systems, Inc. (Reliant
Energy Thermal Systems) which provides energy management and thermal
systems for site-specific projects, such as buildings, universities,
hospitals and district cooling systems for cities and large
metropolitan areas
o various office buildings and other real estate used in the Company's
business operations
o unallocated corporate costs, and
o inter-segment eliminations
Reliant Energy Retail, a wholly owned subsidiary of Resources Corp.,
markets natural gas and related energy services to commercial and industrial
customers who are served by large local gas distribution companies or are
connected to interstate and intrastate pipelines offering unbundled
transportation services. Included in Reliant Energy Retail's retail marketing
operations are subsidiaries of Resources Corp. that market and deliver natural
gas to large volume customers at market-based rates. Reliant Energy Retail also
sells natural gas in the deregulated Georgia market to residential and
commercial customers.
In September 1999, Reliant Energy Communications received its Special
Provider Certificate of Operating Authority from the Texas Utility Commission,
which allows it to offer telecommunications products and services
17
20
throughout the state of Texas. Reliant Energy Communications is a
facilities-based carrier, offering enhanced data, voice and Internet services to
customers in Texas, with an initial focus on the business market in Houston.
Initial data services include private line, Internet access, frame relay, ATM,
ISDN and DSL. Switched voice products include a full range of local dialtone,
long-distance and wireless services. In October 1999, Reliant Energy
Communications became the first carrier to file the newly approved Texas 271
Agreement (T2A) with the Texas Utility Commission. The T2A is a standardized
interconnection agreement, which has been developed as part of the Federal
Telecommunications Act 271 implementation process by representatives of
industry, the Texas Utility Commission staff and Southwestern Bell in an effort
to ensure that competitive local exchange carriers (CLECs) receive comparable
terms and conditions from Southwestern Bell.
REGULATION
The Company is subject to regulation by various federal, state, local and
foreign governmental agencies, including the regulations described below.
PUBLIC UTILITY HOLDING COMPANY ACT
Holding Company Status. Reliant Energy is both a holding company and an
electric utility as defined in the Public Utility Holding Company Act of 1935
(the 1935 Act); however, it is exempt from regulation as a holding company under
Section 3(a)(2) of the 1935 Act. Although Resources Corp. 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. Reliant Energy and Resources Corp. 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.
Section 33(a)(1) of the 1935 Act exempts foreign utility company affiliates
of Reliant Energy and Resources Corp. from regulation as "public utility
companies," thereby permitting Reliant Energy and Resources Corp. 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 having received certification from each state commission having
jurisdiction over the retail rates of any electric or gas utility company
affiliated with Reliant Energy or Resources Corp. that such commission has the
authority and resources to protect ratepayers subject to its jurisdiction and
that it intends to exercise its authority. The Texas Utility Commission and the
state regulatory commissions exercising jurisdiction over Resources Corp.
(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 Reliant Energy and
Resources Corp.) 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 debt and stockholders'
equity, 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. In recent years, 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 2000.
FEDERAL ENERGY REGULATORY COMMISSION (FERC)
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. The
FERC
18
21
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 the 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.
The FERC has recently adopted several changes to its regulation of
interstate pipeline construction projects and transportation rates and services.
In September 1999, the FERC issued a policy statement providing that, in most
instances, customers receiving service through new pipeline facilities will be
required to bear the cost of the facilities. In addition, companies seeking to
construct new pipeline facilities must demonstrate that the benefits of the
proposed facilities will outweigh any adverse effects on affected landowners,
the environment, the pipeline's customers, or existing pipelines and their
customers. On February 9, 2000, the FERC issued Order No. 637, which introduces
several measures to increase competition for interstate pipeline transportation
services. Order No. 637 authorizes interstate pipelines to propose
term-differentiated and peak/off-peak rates, and requires pipelines, including
MRT and REGT, to make tariff filings by May 1, 2000 to expand pipeline service
options for customers.
The California plants owned by the Company are subject to FERC jurisdiction
and regulation. The FERC permits the California plants to make sales at
negotiated market-based rates and has waived most of the regulatory requirements
otherwise applicable to regulated public utilities under the Federal Power Act.
Prior to January 1, 2000, special rules applied to the two California plants
which had been designated as "reliability must-run" facilities by the California
Independent System Operator Corporation. Units at these plants were required to
provide electric service to the system operator for reliability purposes at
rates and under terms and conditions regulated by the FERC. These plants have
not been designated as "reliability must-run" for the calendar year 2000 and
therefore may sell electricity at market-based rates at all times.
Reliant Energy Services is also subject to FERC 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).
19
22
STATE AND LOCAL UTILITY REGULATIONS
Electric Operations. Currently, Reliant Energy HL&P 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, Reliant Energy HL&P holds non-exclusive franchises to provide electric
service within the incorporated municipalities in the service territory of
Electric Operations. None of these franchises expire before 2007.
Reliant Energy HL&P's electric utility operations are currently subject to
traditional cost-of-service regulation at rates regulated by the Texas Utility
Commission. In June 1999, Texas passed the Legislation, which will significantly
change the regulation of electric utility operators in the State of Texas. For
additional information, including information about the Legislation's effect on
competition in the retail electric and electric generation markets in Texas, see
"--Electric Operations-- Deregulation and Competition," "Management's Discussion
and Analysis of Financial Condition and Results of Operations of the
Company--Certain Factors Affecting Future Earnings of the Company--Competition
and Restructuring of the Texas Electric Utility Industry" and Note 3 to the
Company's Consolidated Financial Statements, which Sections and Note are
incorporated herein by reference. This competition is scheduled to commence
January 1, 2002.
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 expire
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 are currently a party to any material 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 had 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 at the facility. Currently, the South Texas Project continues to dispose
of its low-level nuclear waste under a short-term agreement at the Barnwell
facility.
An interstate compact among Texas, Maine and Vermont has sole access to a
Texas waste disposal facility. The Texas Natural Resource Conservation
Commission 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.
20
23
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 Reliant Energy HL&P's share of this assessment from
prior years.
For information regarding the NRC's regulation of nuclear decommissioning
trust funds, see Note 6 to the Company's Consolidated Financial Statements.
FOREIGN REGULATION
For a description of the contractual agreements and protocol under which
UNA will operate during the transition to a deregulated market, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations of the Company -- Results of Operations by Business Segment --
Reliant Energy Europe," which section is incorporated herein by reference.
ENVIRONMENTAL MATTERS
The Company is 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. In general,
Federal statutes develop requirements which then are implemented by state and
local entities through enabling ordinances or legislation specific to the area.
As part of the Federal Clean Air Act Amendments of 1990, requirements and
schedules for attainment of health based air standards were developed. In Texas,
these requirements are being determined by the Texas Natural Resources
Conservation Commission (TNRCC) for areas that do not attain the federally
prescribed standards. The Houston area has been designated a non-attainment area
for ozone, and preliminary work done by the TNRCC indicates substantial (as much
as 90%) reductions in oxides of nitrogen (NOx), a product of the combustion
process associated with the generation of electric energy and a contributor to
ozone formation, may be necessary. While regulations have not been finalized for
the Houston area, the Company estimates that reductions of the magnitude
contemplated by the TNRCC will require substantial expenditures in the years
2000 through 2003 and will require modifications to reduce emissions from most
of the Company's generating assets in Texas. See "--Clean Air Act Expenditures"
below.
The Clean Air Act also required a study to determine if additional
regulations are needed to improve visibility in the southwestern United States.
Reliant Energy does not expect that this study will require the installation of
additional pollution controls on the Company's generating units, including the
generating units acquired by, or expected to be completed by, the Company.
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 Sciences 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
facilities.
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 emission limitations for NOx under the Clean Air
Act. NOx reduction costs incurred by Electric Operations generating units in the
Houston, Texas area totaled approximately $7 million in 1999 and $7 million in
1998. The TNRCC is currently considering additional NOx reduction requirements
for electric generating units and other industrial sources located in the
Houston metropolitan area and the eastern half of Texas as a means to attain the
Clean Air Act standard for ozone. Although the magnitude and timing of these
requirements will not be established by the TNRCC until November 2000, NOx
reductions approaching the 90% level of emissions are anticipated. Expenditures
for NOx controls on Electric Operations generating units have been estimated at
$500 to $600 million during the period 2000 through 2003, with an estimated $80
million to be incurred during 2000. In addition, the Legislation created a
program mandating air emissions reductions for certain generating facilities of
Electric Operations. The Legislation provides for stranded cost recovery for
costs associated with this obligation incurred before May 1, 2003. For further
information regarding the Legislation, see Note 3 to the Company's Consolidated
Financial Statements.
The Company's 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.
21
24
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 --
Environmental Expenditures," Note 14(h) to the Company's Consolidated Financial
Statements and Note 8(d) to Resources Corp.'s Consolidated Financial Statements.
Compliance with federal, state and local laws governing the discharge of
materials into the environment, or otherwise intended to protect the
environment, is not expected to have a material adverse impact on the
consolidated results of operations or financial position of the Company.
EMPLOYEES
As of December 31, 1999, the Company had 14,256 full-time employees. The
following table sets forth the number of the Company's employees by business
segment as of December 31, 1999:
SEGMENT NUMBER
- ------- ------
Electric Operations ............ 6,739
Natural Gas Distribution ....... 4,879
Interstate Pipelines ........... 570
Wholesale Energy ............... 477
Reliant Energy Europe .......... 933
Reliant Energy Latin America ... 84
Corporate ...................... 574
------
Total .......................... 14,256
======
The number of employees of Reliant Energy and its subsidiaries who are
represented by unions or other collective bargaining groups include (i) Electric
Operations, 2,789; (ii) Natural Gas Distribution, 1,557; (iii) Wholesale Energy,
5 and (iv) Reliant Energy Europe, 650.
22
25
EXECUTIVE OFFICERS OF RELIANT ENERGY
(AS OF MARCH 10, 2000)
OFFICER
NAME AGE (1) SINCE PRESENT POSITION
- -------------------- -------- ----- -----------------------------------------
R. STEVE LETBETTER 51 1978 Chairman, President, Chief Executive
Officer and Director
ROBERT W. HARVEY 44 1999 Vice Chairman
LEE W. HOGAN 55 1990 Vice Chairman and Director
STEPHEN W. NAEVE 52 1988 Vice Chairman and Chief Financial Officer
HUGH RICE KELLY 57 1984 Executive Vice President, General Counsel
and Corporate Secretary
MARY P. RICCIARDELLO 44 1993 Senior Vice President and Comptroller
DAVID M. MCCLANAHAN 50 1986 President and Chief Operating Officer,
Reliant Energy Delivery Group
JOE BOB PERKINS 39 1996 President and Chief Operating Officer,
Reliant Energy Wholesale Group
- -----------------
(1) As of December 31, 1999
Mr. Letbetter has served as Chairman of Reliant Energy since January 2000 and as
President and Chief Executive Officer of Reliant Energy since June 1999. He has
been a director of Reliant Energy since 1995. He has served in various executive
officer capacities with the Company since 1978.
Mr. Harvey has served as Vice Chairman of Reliant Energy since June 1999. Prior
to joining the Company, he served as a director in the Houston office of
McKinsey & Company, Inc.
Mr. Hogan has served as Vice Chairman of Reliant Energy since June 1999. He has
been a director of Reliant Energy since 1995. He has served in various executive
officer capacities with the Company since 1990, including President and Chief
Operating Officer of Reliant Energy International between 1993 and 1997.
Mr. Naeve has served as Vice Chairman of Reliant Energy since June 1999 and as
Chief Financial Officer of Reliant Energy since 1997. Between 1997 and 1999, he
served as Executive Vice President and Chief Financial Officer of Reliant
Energy. He has served in various executive officer capacities with the Company
since 1988, including Vice President - Strategic Planning and Administration
between 1993 and 1996.
Mr. Kelly has served as Executive Vice President, General Counsel and Corporate
Secretary of Reliant Energy since 1997. Between 1984 and 1997, he served as
Senior Vice President, General Counsel and Corporate Secretary of Reliant
Energy.
Ms. Ricciardello has served as Senior Vice President and Comptroller of Reliant
Energy since June 1999 and as Vice President and Comptroller of Reliant Energy
since 1996. She has served in various executive officer capacities with the
Company since 1993.
23
26
Mr. McClanahan has served as President and Chief Operating Officer of the
Reliant Energy Delivery Group since 1999. Previously, he served as President and
Chief Operating Officer of the Reliant Energy HL&P division from 1997 to 1999.
He has served in various executive officer capacities with the Company since
1986, including Group Vice President - Finance and Regulatory Relations of
Reliant Energy HL&P from 1993 to 1996.
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 Reliant Energy 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. and
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.
ITEM 2. PROPERTIES.
CHARACTER OF OWNERSHIP
The Company and Resources own their principal properties in fee, except
that most electric lines and gas mains are located, pursuant to easements and
other rights, on public roads or on land owned by others.
Substantially all of the real estate, electric distribution system
properties, buildings and franchises owned directly by Reliant Energy (excluding
real estate and other properties of subsidiaries of Reliant Energy) are subject
to a lien created under a Mortgage and Deed of Trust dated as of November 1,
1944 (as supplemented, Mortgage) between Reliant Energy 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 Reliant Energy Latin America and Wholesale
Energy 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, 1999, Reliant Energy HL&P
owned 12 electric generating stations (62 generating units) with a combined
turbine nameplate rating of 13,554,608 KW, including the Company's interest in
the South Texas Project.
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,
with a combined turbine nameplate rating of 2,623,676 KW, in which the Company
has a 30.8% ownership interest.
Substations. As of December 31, 1999, the Company owned 215 major
substation sites (242 substations) having a total installed rated transformer
capacity of 54,763 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, 1999, the Company owned
25,535 pole miles of overhead distribution lines and 3,646 circuit miles of
overhead transmission lines, including 502 circuit miles operated at 69,000
volts, 2,062 circuit miles operated at 138,000 volts and 1,082 circuit miles
operated at 345,000 volts.
24
27
Electric Lines -- Underground. As of December 31, 1999, the Company owned
12,348 circuit miles of underground distribution lines and 14.9 circuit miles of
underground transmission lines, including 6.8 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.
INTERSTATE PIPELINES
Resources owns and operates approximately 8,200 miles of gas transmission
lines and provides transportation service to various shippers across eight
states in the south-central and midwestern United States. Resources also owns
and operates 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
As of December 31, 1999, Wholesale Energy owned and operated six electric
generating stations (18 generating units) with a combined nameplate rating of
4,515 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. Resources 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.
RELIANT ENERGY EUROPE
For information regarding the investments of Reliant Energy Europe, see
"Business -- Reliant Energy Europe" in Item 1 of this Form 10-K, which
information is incorporated herein by reference.
RELIANT ENERGY LATIN AMERICA
For information regarding the investments of Reliant Energy Latin America,
see "Business -- Reliant Energy Latin America" in Item 1 of this Form 10-K,
which information is incorporated herein by reference.
CORPORATE
For information regarding the properties of Corporate, see "Business --
Corporate" in Item 1 of this Form 10-K.
25
28
ITEM 3. LEGAL PROCEEDINGS.
(a) Reliant Energy.
For a description of certain legal and regulatory proceedings affecting the
Company, see Notes 3, 4, 14(h) and 14(i) to the Company's Consolidated Financial
Statements, which notes are incorporated herein by reference.
(b) Resources Corp.
For a description of certain legal and regulatory proceedings affecting
Resources, see Note 8(d) to Resources' Consolidated Financial Statements, which
note is incorporated herein by reference.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
No matters were submitted to a vote of Reliant Energy's security holders
during the fourth quarter of the fiscal year ended December 31, 1999.
26
29
PART II
ITEM 5. MARKET FOR THE COMPANY'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS.
As of March 10, 2000, Reliant Energy's common stock was held of record by
approximately 80,930 shareholders. Reliant Energy's common stock is listed on
the New York and Chicago Stock Exchanges and is traded under the symbol "REI."
All of Resources Corp.'s common stock is held by Reliant Energy.
The following table sets forth the high and low sales prices of Reliant
Energy's common stock on the composite tape during the periods indicated, as
reported by Bloomberg, and the dividends declared for such periods. Dividend
payout was $1.50 per share in both 1999 and 1998. The dividend declared during
the fourth quarter of 1999 is payable in March 2000.
MARKET PRICE DIVIDEND
------------------------- DECLARED
HIGH LOW PER SHARE
----------- ---------- ---------
1999
First Quarter............................... $ 0.375
January 6................................. $ 32 1/4
March 31.................................. $ 26 1/16
Second Quarter.............................. $ 0.375
April 14.................................. $ 25 1/2
May 25.................................... $ 31 11/16
Third Quarter............................... $ 0.375
September 3............................... $ 28 5/8
September 28.............................. $ 26 5/16
Fourth Quarter.............................. $ 0.375
October 4................................. $ 28 7/16
December 31............................... $ 22 7/8
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
The closing market price of Reliant Energy's common stock on December 31,
1999 was $22 7/8 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.
27
30
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. In July
1995, the Company sold its former cable television subsidiary, the operations of
which were accounted for as discontinued operations. The selected financial data
includes the financial statement effect of UNA and Resources since the October
1999 acquisition and August 1997 acquisition, respectively. Both acquisitions
were accounted for under the purchase method. See Note 2 to the Company's
Consolidated Financial Statements for additional information regarding these
acquisitions.
YEAR ENDED DECEMBER 31,
------------ ------------ ------------ ------------ ------------
1999 1998 1997 1996 1995
------------ ------------ ------------ ------------ ------------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
Revenues ............................................. $ 15,302,810 $ 11,488,464 $ 6,878,225 $ 4,095,277 $ 3,729,271
------------ ------------ ------------ ------------ ------------
Income (loss) from continuing operations before
extraordinary item and preferred dividends
(1)(2)(3) .......................................... $ 1,665,731 $ (141,092) $ 421,110 $ 404,944 $ 397,400
Gain on sale of cable television subsidiary .......... 708,124
Extraordinary item, net of tax (4) ................... 183,261
Preferred dividends .................................. 389 390 162
------------ ------------ ------------ ------------ ------------
Net income (loss) attributable to common
stockholders (1)(2)(3) ............................. $ 1,482,081 $ (141,482) $ 420,948 $ 404,944 $ 1,105,524
============ ============ ============ ============ ============
Basic earnings (loss) per common share:
Continuing operations before extraordinary
item (1)(2)(3) ................................... $ 5.84 $ (.50) $ 1.66 $ 1.66 $ 1.60
Gain on sale of cable television
subsidiary ......................................... 2.86
Extraordinary item, net of tax (4) ................. (.64)
------------ ------------ ------------ ------------ ------------
Basic earnings (loss) per common share (1)(2)(3) ..... $ 5.20 $ (.50) $ 1.66 $ 1.66 $ 4.46
============ ============ ============ ============ ============
Diluted earnings (loss) per common share:
Continuing operations before extraordinary
item (1)(2)(3) ................................... $ 5.82 $ (.50) $ 1.66 $ 1.66 $ 1.60
Gain on sale of cable television subsidiary ........ 2.86
Extraordinary item, net of tax (4) ................. (.64)
------------ ------------ ------------ ------------ ------------
Diluted earnings (loss) per common share(1)(2)(3) .... $ 5.18 $ (.50) $ 1.66 $ 1.66 $ 4.46
============ ============ ============ ============ ============
Cash dividends declared per common share ............. $ 1.50 $ 1.50 $ 1.50 $ 1.50 $ 1.50
Dividend payout ratio from continuing
operations (1)(2)(3) ............................... 26% 96% 89% 94%
Return on average common equity (1)(2)(3)(4) ......... 30.8% (3.1%) 9.7% 10.2% 29.5%
Ratio of earnings from continuing operations to
fixed charges (1)(2)(3)(5) ......................... 5.28 2.40 2.75 2.70
At year-end:
Book value per common share ........................ $ 18.70 $ 15.16 $ 17.28 $ 16.41 $ 16.61
Market price per common share ...................... $ 22.88 $ 32.06 $ 26.75 $ 22.63 $ 24.25
Market price as a percent of book value ............ 122% 211% 155% 138% 146%
Total assets ....................................... $ 26,220,936 $ 19,138,522 $ 18,445,606 $ 12,287,857 $ 11,819,606
Long-term debt obligations, including current
maturities ....................................... $ 9,343,446 $ 7,198,202 $ 5,469,184 $ 3,254,413 $ 3,692,173
Trust preferred securities ......................... $ 705,272 $ 342,232 $ 362,172
Cumulative preferred stock ......................... $ 9,740 $ 9,740 $ 9,740 $ 135,179 $ 402,400
Capitalization:
Common stock equity .............................. 34% 36% 46% 53% 50%
Cumulative preferred stock ....................... 2% 5%
Trust preferred securities ....................... 5% 3% 3%
Long-term debt (including current maturities) .... 61% 61% 51% 45% 45%
Cash consideration for purchase of UNA, net ......... $ 832,742
Purchase of Resources, net of cash acquired ......... $ 1,422,672
Other business acquisitions ......................... $ 38,426
Non-rate regulated electric power plants ............ $ 188,832 $ 292,398
Investments and advances to unconsolidated
subsidiaries ...................................... $ 116,076 $ 445,042 $ 234,852 $ 495,379 $ 49,835
Capital expenditures ................................ $ 1,179,466 $ 743,455 $ 328,724 $ 324,075 $ 397,796
28
31
- -------------
(1) Includes a non-cash, unrealized accounting loss of $409 million, $764
million and $79 million (after-tax), or $1.44, $2.69 and $0.31 earnings per
share, on indexed debt securities in 1999, 1998 and 1997, respectively. For
additional information on the indexed debt securities, see Note 8 to the
Company's Consolidated Financial Statements.
(2) Includes a non-cash, unrealized accounting gain on the Company's investment
in Time Warner common stock of $1.575 billion (after-tax), or $5.53 basic
earnings per share, in 1999. For additional information on the investment
in Time Warner common stock, see Note 8 to the Company's Consolidated
Financial Statements.
(3) Includes a $102 (after-tax) million loss due to the devaluation of the
Brazilian real in 1999, or $0.36 per share. For additional information on
the effect of the devaluation of the Brazilian real on the Company, see
Note 7 to the Company's Consolidated Financial Statements.
(4) The extraordinary item is a loss related to an accounting impairment of
certain generation related regulatory assets of Electric Operations. For
additional information, see Note 3 to the Company's Consolidated Financial
Statements.
(5) Fixed charges exceed earnings by $185 million in 1998.
29
32
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
(Reliant Energy) and its subsidiaries (collectively, the Company) contained in
Item 8 of this Form 10-K.
RELIANT ENERGY, INCORPORATED
The Company is a diversified international energy services company that
provides energy and energy services in North America, Western Europe and Latin
America. It operates one of the nation's largest electric utilities 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 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 an
interstate natural gas pipeline, providing gas transportation, supply, gathering
and storage, and also engages in wholesale energy marketing and trading.
The Company's financial reporting segments include: Electric Operations,
Natural Gas Distribution, Interstate Pipelines, Wholesale Energy, Reliant Energy
Europe, Reliant Energy Latin America and Corporate. For segment reporting
information, see Notes 1(a) and 18 to the Company's Consolidated Financial
Statements. For a description of the segments, see Note 1(a) to the Company's
Consolidated Financial Statements and "Business" in Item 1 of this Form 10-K.
During 1999, the Company completed the first two phases of its acquisition
of N.V. UNA (UNA), a Dutch power generation company. The Company acquired 40%
and 12% of UNA's capital stock on October 7, 1999 and December 1, 1999,
respectively. On March 1, 2000, the Company purchased the remaining 48% of the
shares of UNA. The total purchase price of the acquisition was approximately
$2.4 billion (based on an exchange rate of 2.0565 NLG per U.S. dollar as of
October 7, 1999), which includes a $426 million promissory note to UNA. The
acquisition was accounted for as a purchase. Effective October 1, 1999, the
Company recorded 100% of the operating results of UNA. For additional
information about this acquisition, including the Company's accounting treatment
of the acquisition, see Note 2 to the Company's Consolidated Financial
Statements.
In August 1997, the Company acquired Reliant Energy Resources Corp.
(Resources Corp.) and its subsidiaries (collectively, Resources), a natural gas
gathering, transmission, marketing and distribution company that conducted
business under the name "NorAm Energy Corp." prior to February 1999. The
acquisition was accounted for as a purchase; accordingly, the Company's results
of operations include the results of operations of Resources only for the period
after the acquisition date.
To enhance comparability between reporting periods, certain information in
this Form 10-K is presented on a pro forma basis and reflects the acquisition of
Resources as if it had occurred at the beginning of 1997 and the acquisition of
UNA as if it had occurred at the beginning of 1999 and 1998. Pro forma
purchase-related adjustments for these acquisitions include amortization of
goodwill and the allocation of the fair value of certain assets and liabilities.
In addition, pro forma adjustments have been made to reflect UNA's operating
results in accordance with U.S. generally accepted accounting principles. The
pro forma results of operations are not necessarily indicative of the combined
results of operations that would have occurred had the acquisitions occurred on
such dates.
All dollar amounts in the tables that follow are in millions, except for
per share data.
30
33
CONSOLIDATED RESULTS OF OPERATIONS
ACTUAL
------------------------------------------
TWELVE MONTHS ENDED DECEMBER 31,
------------------------------------------
1999 1998 1997
---------- ---------- ----------
Revenues ................................................... $ 15,303 $ 11,488 $ 6,878
Operating Expenses ......................................... (14,062) (10,022) (5,823)
---------- ---------- ----------
Operating Income ........................................... 1,241 1,466 1,055
Dividend Income ............................................ 26 41 41
Interest Expense and Other Charges ......................... (563) (539) (424)
Unrealized Gain on Time Warner Investment .................. 2,452
Unrealized Loss on Indexed Debt Securities ................. (630) (1,176) (121)
Income Tax (Expense) Benefit ............................... (899) 30 (206)
Extraordinary Item, Net of Tax ............................. (183)
Other Income - Net ......................................... 38 37 76
---------- ---------- ----------
Net Income (Loss) Attributable to Common Stockholders ...... $ 1,482 $ (141) $ 421
========== ========== ==========
Basic Earnings (Loss) Per Share ............................ $ 5.20 $ (0.50) $ 1.66
Diluted Earnings (Loss) Per Share .......................... $ 5.18 $ (0.50) $ 1.66
PRO FORMA
------------------------------------------
TWELVE MONTHS ENDED DECEMBER 31,
------------------------------------------
1999 1998 1997
---------- ---------- ----------
Revenues ................................................... $ 15,784 $ 12,320 $ 10,191
Operating Expenses ......................................... (14,436) (10,681) (8,985)
---------- ---------- ----------
Operating Income ........................................... 1,348 1,639 1,206
Dividend Income ............................................ 26 41 41
Interest Expense and Other Charges ......................... (640) (647) (533)
Unrealized Gain on Time Warner Investment .................. 2,452
Unrealized Loss on Indexed Debt Securities ................. (630) (1,176) (121)
Income Tax (Expense) Benefit ............................... (904) 24 (232)
Extraordinary Item, Net of Tax ............................. (183)
Other Income - Net ......................................... 56 58 76
---------- ---------- ----------
Net Income (Loss) Attributable to Common Stockholders ...... $ 1,525 $ (61) $ 437
========== ========== ==========
Basic Earnings (Loss) Per Share ............................ $ 5.35 $ (0.21) $ 1.55
Diluted Earnings (Loss) Per Share .......................... $ 5.33 $ (0.21) $ 1.55
1999 (Actual) Compared to 1998 (Actual). The Company reported consolidated
earnings in 1999 of $1.482 billion ($5.20 per basic share) compared to a
consolidated net loss of $141 million ($0.50 per share) for 1998. The amount for
1999 reflects a $1.575 billion (after-tax) non-cash, unrealized accounting gain
on the Company's investment in Time Warner (TW) common stock (TW Common); a $409
million (after-tax) non-cash, unrealized accounting loss on indexed debt
securities; a $102 million (after-tax) loss resulting from the effect of the
devaluation of the Brazilian real on equity earnings of the Company's Brazilian
investments; and a $183 million (after-tax) extraordinary loss relating to an
accounting impairment of certain generation related regulatory assets of
Electric Operations. The reported loss for 1998 includes a $764 million
(after-tax) non-cash, unrealized accounting loss on indexed debt securities. For
information regarding the Company's investment in TW Common and Reliant Energy's
indexed debt securities, see Note 8 to the Company's Consolidated Financial
Statements. For information regarding the $183 million extraordinary loss, see
"-- Certain Factors Affecting Future Earnings of the Company -- Competition and
Restructuring of the Texas Electric Utility Industry" and Note 3 to the
Company's Consolidated Financial Statements.
After adjusting for unusual and other charges (as described above) in both
years, net income for 1999 would have been $601 million ($2.11 per share)
compared to $623 million ($2.19 per share) for 1998. The $22 million decrease
31
34
was primarily due to an $80 million, or $0.28 per share, gain on the sale of an
Argentine electric distribution system in 1998 and lower earnings in 1999 for
the Natural Gas Distribution, Interstate Pipelines and Wholesale Energy
segments. These decreases were partially offset by higher earnings in the
Reliant Energy Latin America segment (after adjusting for the loss due to the
devaluation of the Brazilian real) and earnings of Reliant Energy Europe which
acquired UNA in the fourth quarter of 1999 (see Note 2 to the Company's
Consolidated Financial Statements).
1999 (Pro Forma) Compared to 1998 (Pro Forma). Consolidated pro forma
earnings in 1999 were $1.525 billion ($5.35 per basic share) compared to a
consolidated pro forma net loss of $61 million ($0.21 per share) for 1998. After
adjusting for unusual and other charges (as described above) in both years, pro
forma net income for 1999 would have been $644 million ($2.26 per share)
compared to $703 million ($2.48 per share) for 1998. The decrease in the 1999
period can be attributed to the same factors discussed above and a decline in
pro forma operating income of Reliant Energy Europe.
1998 (Actual) Compared to 1997 (Actual). The Company reported a
consolidated net loss for 1998 of $141 million ($0.50 per share) compared to
consolidated net income of $421 million ($1.66 per share) in 1997. The 1998
consolidated net loss resulted from the accounting treatment of Reliant Energy's
indexed debt securities, one series of which was issued in July 1997. The
Company recorded a non-cash, unrealized accounting loss (after-tax) of $764
million on such series of indexed debt securities in 1998. In 1997, the Company
recorded a non-cash, unrealized accounting loss (after-tax) of $79 million on
such series of indexed debt securities, 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 Reliant Energy's indexed debt securities, see
Note 8 to the Company's Consolidated Financial Statements.
After adjusting for unusual and other charges (as described above) in both
years, net income for 1998 would have been $623 million ($2.19 per share)
compared to $463 million ($1.83 per share) in 1997. The $160 million increase in
adjusted net income for 1998 compared to 1997 was due to improved results from
Interstate Pipelines, Wholesale Energy and Reliant Energy Latin America
segments. Net income for 1998 included an $80 million, or $0.28 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 acquisition of Resources. 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 acquisition of Resources.
1998 (Pro Forma) Compared to 1997 (Pro Forma). The consolidated pro forma
net loss for 1998 was $61 million ($0.21 per share) compared to consolidated pro
forma net income of $437 million ($1.55 per share) in 1997. After adjusting for
unusual and other charges (as described above) in both years, pro forma net
income for 1998 would have been $703 million ($2.48 per share) compared to $479
million ($1.70 per share) in 1997. This increase in adjusted pro forma net
income for 1998 compared to 1997 was primarily due to the same factors discussed
above and $80 million of pro forma net income of UNA in 1998.
Interest Expense and Other Charges. In 1999, 1998 and 1997, interest
expense and other charges were $563 million, $539 million and $424 million,
respectively. Increased interest expense and other charges in 1999 compared to
1998 was primarily due to higher levels of short-term borrowings, long-term debt
and trust preferred securities. These increases were associated in part with the
acquisition of shares of UNA in the fourth quarter of 1999, the Company's
additional investment in TW Common in 1999, other acquisitions of businesses and
capital expenditures. The increase in 1999 was partially offset by a decrease in
the average interest rate for long-term debt. The increase in 1998 from 1997 was
primarily attributable to the acquisition of Resources in August 1997 and the
acquisitions of non-rate regulated electric power plants and equity investments
in Latin America in 1998.
Income Tax Expense. The effective tax rate for 1999, 1998, and 1997 was
35.1%, 17.7%, and 32.8% respectively. After adjusting for the following unusual
and other charges: unrealized accounting gain on the investment in TW Common,
unrealized accounting loss on indexed debt securities, loss due to the
devaluation of the Brazilian real, and non-recurring interest income related to
a refund of federal income taxes in 1997, the adjusted effective tax rate for
1999, 1998, and 1997 was 33.0%, 37.9% and 33.1%, respectively. The decrease in
effective tax rate in 1999 compared
32
35
to 1998 was primarily due to the discontinuance of SFAS No. 71, "Accounting for
the Effects of Certain Types of Regulation" (SFAS No. 71), for the generation
operations of Electric Operations. For information regarding the discontinuance
of SFAS No. 71 to the generation operations of Electric Operations, see Note 3
to the Company's Consolidated Financial Statements. The increase in effective
tax rate in 1998 from 1997 was primarily due to non-deductible goodwill
resulting from the acquisition of Resources in August 1997.
RESULTS OF OPERATIONS BY BUSINESS SEGMENT
All business segment data (other than data relating to Electric Operations)
is presented on a pro forma basis and reflects the acquisition of Resources as
if it had occurred at the beginning of 1997 and the acquisition of UNA as if it
had occurred at the beginning of 1999 and 1998.
The following table presents operating income on an actual basis and a pro
forma basis for the years ended December 31, 1999, 1998 and 1997 (in millions).
Certain amounts from the previous years have been reclassified to conform to the
1999 presentation of the financial statements. Such reclassifications do not
affect consolidated earnings.
OPERATING INCOME (LOSS) BY BUSINESS SEGMENT
ACTUAL PRO FORMA
--------------------------------------- ---------------------------------------
YEAR ENDED DECEMBER 31, YEAR ENDED DECEMBER 31,
--------------------------------------- ---------------------------------------
1999 1998 1997 1999 1998 1997
--------- --------- --------- --------- --------- ---------
Electric Operations ............... $ 981 $ 1,002 $ 985 $ 981 $ 1,002 $ 985
Natural Gas Distribution .......... 125 145 57 125 145 156
Interstate Pipelines .............. 113 128 32 113 128 99
Wholesale Energy .................. 45 59 1 45 59 (15)
Reliant Energy Europe ............. 32 139 173
Reliant Energy Latin America ...... (23) 182 20 (23) 182 17
Corporate ......................... (32) (50) (40) (32) (50) (36)
--------- --------- --------- --------- --------- ---------
Total Consolidated ................ $ 1,241 $ 1,466 $ 1,055 $ 1,348 $ 1,639 $ 1,206
========= ========= ========= ========= ========= =========
ELECTRIC OPERATIONS
Electric Operations conducts operations under the name "Reliant Energy
HL&P," an unincorporated division of Reliant Energy. Electric Operations
generates, purchases, transmits and distributes electricity to approximately 1.7
million customers in a 5,000 square mile area on the Texas Gulf Coast, including
Houston, Texas, the nation's fourth largest city.
In June 1999, the Texas legislature adopted the Texas Electric Choice
Plan (Legislation) that substantially amends the regulatory structure governing
electric utilities in Texas in order to allow retail competition beginning on
January 1, 2002. Prior to adoption of the Legislation, Electric Operations'
earnings were 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)
effective January 1, 1998. As a result of the Transition Plan, any earnings
prior to the Legislation above the maximum allowed return cap on invested
capital were offset by additional depreciation of Electric Operations' electric
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 received
base rate credits of 2% in 1998 and 1999. For more information regarding the
Transition Plan, see Notes 1(g) and 4 to the Company's Consolidated Financial
Statements. For more information regarding the Legislation, see Note 3 to the
Company's Consolidated Financial Statements.
33
36
The following table provides summary data regarding the actual results of
operations of Electric Operations for 1999, 1998 and 1997 (in millions):
YEAR ENDED DECEMBER 31,
----------------------------------
1999 1998 1997
-------- -------- --------
Operating Revenues:
Base Revenues(1) ......................... $ 2,968 $ 2,969 $ 2,839
Reconcilable Fuel Revenues(2) ............ 1,515 1,381 1,413
-------- -------- --------
Total Operating Revenues ............... 4,483 4,350 4,252
-------- -------- --------
Operating Expenses:
Fuel and Purchased Power ................. 1,569 1,455 1,477
Operation and Maintenance ................ 916 890 885
Depreciation and Amortization Expense .... 667 663 582
Other Operating Expenses ................. 350 340 323
-------- -------- --------
Total Operating Expenses ............... 3,502 3,348 3,267
-------- -------- --------
Operating Income ............................ $ 981 $ 1,002 $ 985
======== ======== ========
- --------
(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 of fuel. See "--Operating Revenues--
Electric Operations."
OPERATING INCOME - ELECTRIC OPERATIONS
1999 Compared to 1998. Electric Operations' operating income for the year
ended December 31, 1999 was $981 million compared to $1,002 million for the
same period in 1998. The $21 million decrease was primarily due to the effects
of milder weather and additional base rate credits provided under the Transition
Plan partially offset by continued strong customer growth.
1998 Compared to 1997. Electric Operations' 1998 operating income was
$1,002 million compared to $985 million the previous year. The increase of $17
million in operating income was due to higher revenues from the unusually hot
weather in 1998 and customer growth partially offset by base rate credits
provided under the Transition Plan.
OPERATING REVENUES - ELECTRIC OPERATIONS
1999 Compared to 1998. Electric Operations' base revenues were $2,968
million for 1999, a decrease of $1 million from 1998. The effects of milder
weather in 1999 as compared to 1998 and additional base rate credits in 1999
were offset by continued strong customer growth and increased usage per
customer. Total KWH sales were consistent between the two periods.
Electric Operations' 10% increase in reconcilable fuel revenue in 1999
resulted primarily from increased natural gas prices. The Texas Utility
Commission provides for recovery of certain fuel and purchased power costs
through a fixed fuel factor included in electric rates. 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 Company's Consolidated Balance Sheets as deferred credits or
regulatory assets, respectively. 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
34
37
31, 1997, with some exceptions including a disallowance of $12 million in fuel
expense relating to the three-year period ending July 31, 1997.
1998 Compared to 1997. Electric Operations' $130 million increase in 1998
base revenues over 1997 was 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 credit
which reduced revenues by $74 million. 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 in 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 1999 was $1.87 per million British Thermal Units (MMBtu)
($2.47 for natural gas, $1.76 for coal, $1.42 for lignite, and $0.44 for
nuclear). The average cost of fuel used by Electric Operations in 1998 was $1.70
per MMBtu ($2.18 for natural gas, $1.78 for coal, $1.19 for lignite, and $0.48
for nuclear). The average cost of fuel used by Electric Operations in 1997 was
$1.87 per MMBtu ($2.60 for natural gas, $2.02 for coal, $1.08 for lignite and
$0.54 for nuclear).
1999 Compared to 1998. Fuel and purchased power expenses in 1999 increased
by $114 million or 8% over 1998 expenses. The increase is a result of higher
costs for natural gas and higher reconcilable cost per unit of lignite. The
increase resulting from higher unit cost of fuel was partially offset by a $12
million charge to non-reconcilable fuel in 1998 as discussed above.
1998 Compared to 1997. Fuel and purchased power expenses in 1998 decreased
by $22 million or 1% below 1997 expenses. The decrease was driven by a decrease
in the average unit cost of natural gas.
OPERATION AND MAINTENANCE EXPENSES, DEPRECIATION, AMORTIZATION AND OTHER -
ELECTRIC OPERATIONS
1999 Compared to 1998. Operation, maintenance and other operating expenses
increased $36 million in 1999, including $38 million due to transmission tariffs
within ERCOT. A portion of these transmission expenses were offset by an
increase of $28 million in transmission tariff revenue. State franchise taxes
increased $13 million in 1999 compared to 1998.
1998 Compared to 1997. Operation, maintenance and other operating expenses
increased $22 million in 1998 compared to 1997, including $9 million due to
transmission tariffs within ERCOT. These transmission expenses were largely
offset by an increase of $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
1997, as provided by the Transition Plan. The comparative increase was mitigated
because amortization of the investment in lignite reserves associated with a
canceled generation project was $62 million lower in 1998 than in 1997. For
information regarding the depreciation and amortization expense of Electric
Operations recorded in 1999 and 1998 pursuant to the Legislation and Transition
Plan, see Notes 1(d), 1(g), 3 and 4 to the Company's Consolidated Financial
Statements.
35
38
NATURAL GAS DISTRIBUTION
Natural Gas Distribution conducts operations through three divisions of
Resources Corp., Reliant Energy Arkla, Reliant Energy Entex and Reliant Energy
Minnegasco. Natural Gas Distribution's operations consist of intrastate natural
gas sales to, and natural gas transportation for residential, commercial and
industrial customers in Arkansas, Louisiana, Minnesota, Mississippi, Oklahoma
and Texas.
The Company has retained a financial advisor to assist it in evaluating
strategic alternatives for Reliant Energy Arkla and Reliant Energy Minnegasco,
including divestiture.
The following table provides summary data regarding the actual results of
operations of Natural Gas Distribution for 1999 and 1998 and unaudited pro forma
results of operations for 1997 (in millions):
ACTUAL PRO FORMA
------------------------------- -------------
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31,
------------------------------- -------------
1999 1998 1997
------------- ------------- -------------
Operating Revenues:
Base Revenues ................................. $ 802 $ 845 $ 874
Recovered Gas Revenues ........................ 1,095 1,034 1,388
------------- ------------- -------------
Total Operating Revenues .................... 1,897 1,879 2,262
------------- ------------- -------------
Operating Expenses:
Natural Gas ................................... 1,102 1,085 1,440
Operation and Maintenance ..................... 453 426 439
Depreciation and Amortization ................. 132 131 125
Other Operating Expenses ...................... 85 92 102
------------- ------------- -------------
Total Operating Expenses .................... 1,772 1,734 2,106
------------- ------------- -------------
Operating Income ................................. $ 125 $ 145 $ 156
============= ============= =============
Throughput Data (in billion cubic feet (BCF)):
Residential and Commercial Sales .............. 287 286 326
Industrial Sales .............................. 56 56 59
Transportation ................................ 46 44 42
------------- ------------- -------------
Total Throughput ............................ 389 386 427
============= ============= =============
1999 (Actual) Compared to 1998 (Actual). Natural Gas Distribution's
operating income was $125 million in 1999 compared to $145 million in 1998. The
$20 million decrease was primarily attributable to an increase in operating
expenses, in particular employee benefits, and costs associated with the
implementation of an enterprise wide information system.
The $18 million or 1% increase in 1999 operating revenues compared to 1998
is primarily due to an increase in the price of purchased gas. Mild weather in
1999 continued to negatively impact the demand for natural gas heating.
1998 (Actual) Compared to 1997 (Pro Forma). Operating income was $145
million in 1998 compared to pro forma operating income of $156 million in 1997.
The $11 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.
The $383 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.
36
39
INTERSTATE PIPELINES
Interstate Pipelines provides interstate gas transportation and related
services through two wholly owned subsidiaries of Resources Corp., Reliant
Energy Gas Transmission Company (REGT) and Mississippi River Transmission
Corporation (MRT).
The Company has retained a financial advisor to assist it in evaluating
strategic alternatives for Interstate Pipelines, including divestiture.
The following table provides summary data regarding the actual results of
operations of Interstate Pipelines for 1999 and 1998 and unaudited pro forma
results of operations for 1997 (in millions):
ACTUAL PRO FORMA
-------------------------------- -------------
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31,
-------------------------------- -------------
1999 1998 1997
------------- ------------- -------------
Operating Revenues ................. $ 275 $ 282 $ 295
Operating Expenses:
Natural Gas ..................... 27 32 51
Operation and Maintenance ....... 71 64 82
Depreciation and Amortization ... 49 44 48
Other Operating Expenses ........ 15 14 15
------------- ------------- -------------
Total Operating Expenses ...... 162 154 196
------------- ------------- -------------
Operating Income ................... $ 113 $ 128 $ 99
============= ============= =============
Throughput Data (in BCF):
Natural Gas Sales .................. 15 16 18
Transportation ..................... 836 825 911
Elimination(1) .................. (14) (15) (17)
------------- ------------- -------------
Total Throughput ................... 837 826 912
============= ============= =============
- -------
(1) Elimination of volumes both transported and sold.
1999 (Actual) Compared to 1998 (Actual). Interstate Pipelines' operating
income for 1999 was $113 million compared to $128 million for 1998. The $15
million decrease was due primarily to the settlement of a dispute related to
certain gas purchase contracts that resulted in the recognition of $6 million of
revenues in 1998, a reduction in depreciation and amortization in 1998 of $5
million related to a rate case settlement and an increase in operating expenses
in 1999, primarily employee benefit expenses.
Operating revenue for Interstate Pipelines decreased by $7 million in 1999
compared to 1998. The decrease was primarily attributable to the settlement of
outstanding gas purchase contract litigation in 1998 as discussed above. Natural
gas expense decreased $5 million in 1999 compared to 1998 primarily due to
expiration of gas supply contracts. Operation and maintenance expense increased
$7 million in 1999 as compared to 1998 primarily due to increases in employee
benefit expenses. Depreciation and amortization expense increased $5 million in
1999 due to a rate settlement recorded in 1998 as discussed above. The rate
settlement, effective January 1998, provided for a $5 million reduction in MRT's
depreciation rates retroactive to July 1996.
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 $29 million 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 as discussed above. 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.
37
40
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 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 1998 as discussed above. The 9% decline in total throughput
reflected the impact of unseasonably warm winter weather.
Interstate Pipelines' 1998 operating expenses declined $42 million in
comparison to 1997 pro forma operating expenses. Contributing to the decrease
were the MRT rate settlement in 1998, the impact of cost control initiatives and
reduced pension and benefit expenses.
Natural gas expense decreased $19 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 $18
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,
reduced pension and benefit expenses 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 1998.
During 1999 and 1998, Interstate Pipelines' largest unaffiliated customer
was a natural gas utility that serves the greater St. Louis metropolitan area in
Illinois and Missouri. Revenues from this customer are generated pursuant to
several long-term firm storage and transportation agreements that currently are
scheduled to expire at various dates between October 2000 and May 2001.
Interstate Pipelines 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 could be adversely affected.
WHOLESALE ENERGY
Wholesale Energy conducts its operations through (i) Reliant Energy Power
Generation, Inc. (collectively with its subsidiaries, Power Generation), (ii)
Reliant Energy Services, Inc. (Reliant Energy Services) and (iii) Reliant Energy
Field Services, Inc.
The Company has retained a financial advisor to assist it in evaluating
strategic alternatives for Reliant Energy Field Services, Inc., including
divestiture.
Wholesale Energy includes the acquisition, development and operation of,
and sales of capacity, energy and ancillary services from domestic unregulated
power generation facilities; wholesale energy trading, marketing and risk
management activities in North America; and domestic natural gas gathering
activities. Power Generation acquires and develops non-rate regulated power
generation facilities. From March 1997 through December 31, 1999, the Company
invested approximately $611 million in the acquisition and development of
domestic non-rate regulated power generation projects. As of December 31, 1999,
Power Generation had entered into commitments associated with various domestic
generation projects amounting to $324 million along with commitments to acquire
various generating equipment totaling $318 million for delivery from 2000 to
2001 that are to be used in future development projects. In February 2000, Power
Generation signed a definitive agreement to purchase from Sithe Energies, Inc.
its non-rate regulated power generating assets and sites located in
Pennsylvania, New Jersey and Maryland having a net generating capacity of more
than 4,200 megawatts for an aggregate purchase price of $2.1 billion, subject to
certain adjustments. The acquisition is expected to close in the second quarter
of 2000 and is subject to obtaining certain regulatory approvals and satisfying
other closing conditions. 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.
38
41
To minimize the Company's risks associated with fluctuations in the price
of natural gas and transportation, the Company, primarily through Reliant Energy
Services, enters into futures transactions, swaps and options in order to hedge
against market price changes affecting (i) certain commitments to buy, sell and
move electric power, natural gas, crude oil and refined products, (ii) existing
natural gas storage and heating oil inventory, (iii) future power sales and
natural gas purchases 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 and
weather derivatives in its trading and price risk management activities. For a
discussion of the Company's accounting treatment of derivative instruments, see
Note 5 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 energy trading, marketing and risk management
activities complement its strategy of developing and/or acquiring non-rate
regulated generation assets in key markets. Reliant Energy Services purchases
fuel to supply 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' infrastructure including software, trading and risk control
resources.
The following table provides summary data regarding the actual results of
operations of Wholesale Energy for 1999 and 1998 and unaudited pro forma results
of operations for 1997 (in millions):
ACTUAL PRO FORMA
------------------------------- -------------
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31,
------------------------------- -------------
1999 1998 1997
------------- ------------- -------------
Operating Revenues ......................................................... $ 7,949 $ 4,456 $ 3,042
Operating Expenses:
Natural Gas ............................................................. 3,959 2,413 2,645
Purchased Power ......................................................... 3,729 1,829 313
Operation and Maintenance ............................................... 184 132 90
Depreciation and Amortization ........................................... 26 18 7
Other Operating Expenses ................................................ 6 5 2
------------- ------------- -------------
Total Operating Expenses ............................................ 7,904 4,397 3,057
------------- ------------- -------------
Operating Income ........................................................... $ 45 $ 59 $ (15)
============= ============= =============
Operations Data:
Natural Gas (in BCF):
Sales ................................................................. 1,820 1,164 958
Gathering ............................................................. 270 237 242
------------- ------------- -------------
Total ............................................................... 2,090 1,401 1,200
============= ============= =============
Electricity (in MMWH):
Wholesale Power Sales ................................................. 112.1 65.2 25.0
============= ============= =============
1999 (Actual) Compared to 1998 (Actual). Wholesale Energy reported
operating income of $45 million compared to $59 million for 1998. The $14
million decrease was due primarily to a decline in market prices for electricity
in the California market caused by milder than normal weather and increased
hydroelectric generation sold into the California market by competitors. This
decline more than offset significant increases in operating income in the
trading and marketing operation of Wholesale Energy.
Operating revenues for Wholesale Energy were $7.9 billion in 1999, a 78%
increase from 1998. The increase in revenues was primarily due to increased
trading volumes for power, gas and oil, as well as higher sales prices for these
same commodities.
39
42
Natural gas and purchased power expense increased $3.4 billion in 1999, an
81% increase from 1998. The increase was primarily due to the corresponding
increase in trading sales volumes. Trading and marketing margin percentages
remained consistent between the two periods. Operation and maintenance expenses
in 1999 increased $52 million from 1998. The increase was primarily due to
increased operating expenses for the California plants which were acquired in
May 1998, increased development costs, and higher levels of trading and
marketing staffing to support the higher sales and expanded marketing efforts.
Depreciation and amortization in 1999 increased $8 million from 1998 due
primarily to a full year of depreciation for the California plants as well as
additional assets placed into operation during 1999.
1998 (Actual) Compared to 1997 (Pro Forma). Wholesale Energy reported
operating income of $59 million in 1998 compared to a pro forma loss of $15
million in 1997. This $74 million increase was due to improved operating results
of both non-rate regulated generating assets and 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 in the trading and marketing operations, as discussed below.
In 1997, operating income was negatively affected by hedging losses associated
with sales under peaking contracts and losses from the sale of unhedged natural
gas held in storage in the first quarter of 1997 totaling $17 million.
Operating revenues in 1998 increased $1.4 billion, a 46% increase from pro
forma 1997 operating revenues, due almost entirely to an increase in wholesale
power sales.
Operating expense in 1998 increased $1.3 billion, or 44% 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 in 1998 decreased $232 million, or 9%, compared to pro forma 1997 due
to the reduction in the price of natural gas in 1998. Operation and maintenance
expense increased $42 million, or 47%, in 1998 as compared to 1997 primarily due
to power plant acquisitions in California and costs associated with staffing
increases in the trading and marketing operation to support increased sales and
marketing efforts. Also contributing to the increase was 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.
RELIANT ENERGY EUROPE
The Company established its Reliant Energy Europe business segment in the
fourth quarter of 1999. Reliant Energy Europe owns, operates and sells power
from generation facilities in the Netherlands and plans to participate in the
emerging wholesale energy trading and marketing industry in the Netherlands and
other countries in Europe.
During 1999, the Company completed the first two phases of its acquisition
of UNA, a Dutch power generation company. The Company acquired 40% and 12% of
UNA's capital stock on October 7, 1999 and December 1, 1999, respectively. On
March 1, 2000, the Company purchased the remaining 48% of the shares of UNA. The
total purchase price of the acquisition was approximately $2.4 billion (based on
an exchange rate of 2.0565 NLG per U.S. dollar as of October 7, 1999), which
includes a $426 million promissory note to UNA. The Reliant Energy Europe
segment includes the operations of UNA and its subsidiaries and the operations
of Reliant Energy Trading & Marketing B.V. (Reliant Energy Marketing Europe),
which operations commenced in the fourth quarter of 1999. For additional
information about this acquisition, including the Company's accounting
treatment of the acquisition, see Note 2 to the Company's Consolidated Financial
Statements.
40
43
The following table provides summary data for the unaudited pro forma
results of operations of Reliant Energy Europe for 1999 and 1998 (in millions):
PRO FORMA
---------------------
YEAR ENDED
DECEMBER 31,
---------------------
1999 1998
-------- --------
Operating Revenues ................. $ 634 $ 832
Operating Expenses:
Fuel and Purchased Power ........ 284 435
Operation and Maintenance ....... 126 136
Depreciation and Amortization ... 85 88
-------- --------
Total Operating Expenses ...... 495 659
-------- --------
Operating Income ................... $ 139 $ 173
======== ========
1999 (Pro Forma) to 1998 (Pro Forma). For the year ended December 31, 1999,
pro forma operating income was $139 million compared to pro forma operating
income of $173 million in 1998. The $34 million decrease in operating income
between periods was primarily due to reduced revenues resulting from lower
regulated returns and recovery of costs. Operating expenses in 1999 associated
with the start-up costs of the European trading and marketing operations also
contributed to the decline.
Pro forma revenues declined in 1999 from 1998 due to lower regulated
returns and recovery of costs and due to the effects of milder weather and
competition from cogeneration and increased import power from other countries,
which reduced the generation of electricity from UNA's plants. Pro forma fuel
expenses declined in 1999 from 1998 primarily due to reduced production of
electricity, as discussed above. Operation and maintenance expenses decreased
due to cost control initiatives and lower ongoing maintenance expenses.
UNA, the other large Dutch generating companies and the Dutch distribution
companies are currently operating under various agreements which regulate, among
other things, the rates UNA may charge for its generation output. Under the
Cooperative Agreement (OvS Agreement), UNA and the other generators agreed to
sell their generating output to a national production pool (SEP) and, in return,
receive a standardized remuneration. The remuneration includes fuel cost,
capital cost and the cost of operations and maintenance expenses. UNA operates
under the protocol (Protocol) which is an agreement under which the generators
agreed to provide capacity and energy to distributors for a total payment of NLG
3.4 billion (approximately $1.6 billion U.S. dollars) over the period 1997
through 2000 plus compensation of actual fuel costs. The OvS will expire
substantially by the beginning of 2001. The Protocol, which was entered into in
order to facilitate the transition from a regulated energy market into an
unregulated energy market, will also expire substantially by the beginning of
2001.
Beginning 2001, UNA will begin operating in a deregulated market. Based on
current estimates, Reliant Energy anticipates that UNA will undergo a
significant decline in revenues in 2001 attributable to the deregulation of the
market. Another factor that will affect the operating results of Reliant Energy
Europe is the imposition in 2002 of standard Dutch corporate tax rates of 35% on
UNA. In 1999 and prior years, UNA was not subject to a corporate income tax.
For additional information on these and certain other factors that may
affect the future results of operations of Reliant Energy Europe, see "--
Certain Factors Affecting Future Earnings of the Company -- Competition --
Reliant Energy Europe Operations."
41
44
RELIANT ENERGY LATIN AMERICA
Reliant Energy Latin America includes the results of operations of Reliant
Energy International, Inc. (Reliant Energy International) and the international
operations of Resources (Resources International). Reliant Energy Latin America
participates in the privatization of generation and distribution facilities and
independent power projects primarily in Latin America.
Reliant Energy is evaluating selling the Company's Latin American assets in
order to pursue business opportunities that are in line with its strategies for
the U.S. and Western Europe.
For information regarding foreign currency matters, including the impact of
the devaluation of the Brazilian real in 1999, see Note 7 to the Company's
Consolidated Financial Statements, "-- Certain Factors Affecting Future Earnings
of the Company -- Risks of Operations in Emerging Markets" 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 7 to the Company's Consolidated
Financial Statements.
The following table provides summary data regarding the actual results of
operations of Reliant Energy Latin America for 1999 and 1998 and pro forma
results of operations for 1997 (in millions):
ACTUAL PRO FORMA
-------------------------- -----------
YEAR ENDED YEAR ENDED
DECEMBER 31, DECEMBER 31,
-------------------------- -----------
1999 1998 1997
---------- ---------- ----------
Operating Revenues ..................... $ 80 $ 259 $ 92
Operating Expenses:
Fuel ................................. 49 25 21
Operation and Maintenance ............ 49 48 50
Depreciation and amortization ........ 5 4 4
---------- ---------- ----------
Total Operating Expenses ..... 103 77 75
---------- ---------- ----------
Operating Income (Loss) ................ $ (23) $ 182 $ 17
========== ========== ==========
1999 (Actual) Compared to 1998 (Actual). In 1999, Reliant Energy Latin
America had an operating loss of $23 million compared to operating income of
$182 million in 1998. The operating loss for 1999 includes a $102 million
(after-tax) loss resulting from the effect of the devaluation of the Brazilian
real on equity earnings of the Company's Brazilian investments. In addition, the
decrease was due to a $138 million pre-tax gain on the sale of a 63% interest in
an Argentine electric distribution company in 1998 partially offset by increased
contributions from Argener and EDESE, a cogeneration project and a utility in
Argentina, and increased equity earnings in 1999.
1998 (Actual) Compared to 1997 (Pro Forma). Reliant Energy Latin America
had operating income of $182 million in 1998 compared to pro forma operating
income of $17 million in 1997. The increase in operating income is primarily due
to a $138 million pre-tax gain on the sale discussed above. Equity earnings from
investments in utility systems in El Salvador and Colombia acquired in 1998 also
contributed to the increase in operating income.
42
45
CORPORATE
Corporate includes the operations of certain non-rate regulated retail
services businesses, a communications business offering enhanced data, voice and
other services to customers in Texas, certain real estate holdings and
unallocated corporate costs.
Corporate had an operating loss of $32 million for 1999 compared to a $50
million operating loss for 1998. The decreased loss was primarily due to
decreased state franchise taxes partially offset by increased general insurance
liability and information system expenses.
Corporate incurred an operating loss of $50 million for 1998 compared to a
pro forma operating loss of $36 million for 1997. The increased loss was
primarily due to development costs, increased expenses associated with
information system costs and increased liabilities associated with certain
compensation plans.
43
46
CERTAIN FACTORS AFFECTING FUTURE EARNINGS OF THE COMPANY
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) state and federal legislative or regulatory developments, (ii)
national or regional economic conditions, (iii) industrial, commercial and
residential growth in service territories of the Company, (iv) the timing and
extent of changes in commodity prices and interest rates, (v) weather variations
and other natural phenomena, (vi) growth in opportunities for the Company's
diversified operations, (vii) the results of financing efforts, (viii) the
ability to consummate and timing of consummation of pending acquisitions and
dispositions, (ix) the speed, degree and effect of continued electric industry
restructuring in North America and Western Europe, and (x) risks incidental to
the Company's overseas operations, including the effects of fluctuations in
foreign currency exchange rates.
In order to adapt to the increasingly competitive environment, 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 businesses and new products, services and
customer strategies.
COMPETITION AND RESTRUCTURING OF THE TEXAS 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.
Texas Electric Choice Plan. In June 1999, the Texas legislature adopted
legislation that substantially amends the regulatory structure governing
electric utilities in Texas in order to allow retail competition beginning with
respect to pilot projects for up to 5% of each utility's load in all customer
classes in June 2001 and for all other customers on January 1, 2002. In
preparation for that competition, the Company expects to make significant
changes in the electric utility operations it conducts through Reliant Energy
HL&P. Under the Legislation, on January 1, 2002, most retail customers of
investor-owned electric utilities in Texas will be entitled to purchase their
electricity from any of a number of "retail electric providers" which will have
been certified by the Texas Utility Commission. Power generators will sell
electric energy to wholesale purchasers, including retail electric providers, at
unregulated rates beginning January 1, 2002. For further information regarding
the Legislation, see Note 3 to the Company's Consolidated Financial Statements.
Stranded Costs. Pursuant to the Legislation, Reliant Energy HL&P will be
entitled to recover its stranded costs (i.e., the excess of net book value of
generation assets, as defined by the Legislation, over the market value of those
assets) and its regulatory assets related to generation. The Legislation
prescribes specific methods for determining the amount of stranded costs and the
details for their recovery. However, during the base rate freeze period from
1999 through 2001, earnings above the utility's authorized return formula will
be applied in a manner to accelerate depreciation of generation related plant
assets for regulatory purposes. In addition, depreciation expense for
transmission and distribution related assets may be redirected to generation
assets for regulatory purposes during that period. The Legislation also provides
for Reliant Energy HL&P, or a special purpose entity, to issue securitization
bonds for the recovery of generation related regulatory assets and stranded
costs. Any stranded costs not recovered through the securitization bonds will be
recovered through a non-bypassable charge to transmission and distribution
customers.
Accounting. At June 30, 1999, the Company performed an impairment test of
its previously regulated electric generation assets pursuant to SFAS No. 121,
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to
be Disposed Of", on a plant specific basis. The Company determined that $797
million of electric generation assets were impaired as of June 30, 1999. Of such
amounts, $745 million relate to the South Texas Project and $52 million relate
to two gas-fired generation plants. The Legislation provides recovery of this
impairment through regulated cash flows during the transition period and
through non-bypassable charges to transmission and distribution customers. As
such, a regulatory asset has been recorded for an amount equal to the impairment
loss and is included on the Company's Consolidated Balance Sheets as a
regulatory asset.
44
47
The impairment analysis requires estimates of possible future market
prices, load growth, competition and many other factors over the lives of the
plants. The resulting impairment loss is highly dependent on these underlying
assumptions. In addition, after January 10, 2004, Reliant Energy HL&P must
finalize and reconcile stranded costs (as defined by the Legislation) in a
filing with the Texas Utility Commission. Any difference between the fair market
value and the regulatory net book value of the generation assets (as defined by
the Legislation) will either be refunded or collected through future
transmission and distribution rates. This final reconciliation allows
alternative methods of third party valuation of the fair market value of these
assets, including outright sale, stock valuations and asset exchanges. Because
generally accepted accounting principles require the Company to estimate fair
market values on a plant-by-plant basis in advance of the final reconciliation,
the financial impacts of the Legislation with respect to stranded costs are
subject to material changes. Factors affecting such change may include
estimation risk, uncertainty of future energy prices and the economic lives of
the plants. If events occur that make the recovery of all or a portion of the
regulatory assets associated with the generation plant impairment loss and
deferred debits created from discontinuance of SFAS No. 71, "Accounting for the
Effects of Certain Types of Regulation" pursuant to the Legislation no longer
probable, the Company will write off the corresponding balance of such assets as
a non-cash charge against earnings.
In the fourth quarter of 1999, Reliant Energy HL&P filed an application to
securitize its generation related regulatory assets as defined by the
Legislation. The Texas Utility Commission, Reliant Energy HL&P and other
interested parties have been discussing proposed methodologies for calculating
the amount of such assets to be securitized. The parties have reached an
agreement in principle as to the amount to be securitized, which reflects the
economic value of the nominal book amount which prior to the deregulation
legislation would have been collected through rates over a much longer time
period. The Company has determined that a pre-tax accounting loss of $282
million exists. Therefore, the Company recorded an after-tax extraordinary loss
of $183 million for this accounting impairment of these regulatory assets in
1999.
Transmission System Open Access. 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.
Transition Plan. In June 1998, the Texas Utility Commission approved the
Transition Plan filed by Reliant Energy HL&P in December 1997. Certain parties
have appealed the order approving the Transition Plan. The provisions of the
Transition Plan expired by their own terms as of December 31, 1999. For
additional information, see Note 4 to the Company's Consolidated Financial
Statements.
COMPETITION -- RELIANT ENERGY EUROPE OPERATIONS
The European energy market is highly competitive. In addition, over the
next several years, an increasing consolidation of the participants in the Dutch
generating market is expected to occur.
Reliant Energy Europe competes in the Netherlands primarily against the
three other largest Dutch generating companies, various cogenerators of electric
power, various alternate sources of power and non-Dutch generators of electric
power, primarily from Germany. At present, the Dutch electricity system has
three operational interconnection points with Germany and two interconnection
points with Belgium. There are also a number of projects that are at various
stages of development and that may increase the number of interconnections in
the future including interconnections with Norway and the United Kingdom. The
Belgian interconnections are used to import electricity from France but a larger
portion of Dutch imports comes from Germany. In 1998, net power imports into the
Netherlands were approximately 11.7 terawatt hours. Based on current
information, it is estimated that net power imports into the Netherlands in 1999
increased significantly from 1998.
45
48
In 1999, UNA and the three other largest Dutch generators supplied
approximately 60% of the electricity consumed in the Netherlands. Smaller Dutch
producers supplied about 28% and the remainder was imported. The Dutch
electricity market is expected to be gradually opened for wholesale competition
including certain commercial and industrial customers beginning in 2001.
Competition is expected to increase in subsequent years and it is anticipated
that the market for small businesses and residential customers will become open
to competition by 2007. The timing of the opening of these markets is subject,
however, to change at the discretion of the Minister of Economic Affairs.
The trading and marketing operations of Reliant Energy Europe will also be
subject to increasing levels of competition. As of March 1, 2000, there were
approximately 25 trading and marketing companies registered with the Amsterdam
Power Exchange. Competition for marketing customers is intense and is expected
to increase with the deregulation of the market. The primary elements of
competition in both the generation and trading and marketing side of Reliant
Energy Europe's business operations are price, credit-support and supply and
delivery reliability.
COMPETITION -- OTHER OPERATIONS
Wholesale Energy. By the third quarter of 2000, Reliant Energy expects that
the Company will own and operate over 8,000 MW of non-rate regulated electric
generation assets that serve the wholesale energy markets located in the states
of California and Florida, and the Southwest, Midwest and Mid-Atlantic regions
of the United States. Competitive factors affecting the results of operations of
these generation assets include: new market entrants, construction by others of
more efficient generation assets, the actions of regulatory authorities and
weather.
Other competitors operate power generation projects in most of the regions
where the Company has invested in non-rate regulated generation assets. Although
local permitting and siting issues often reduce the risk of a rapid growth in
supply of generation capacity in any particular region, over time, projects are
likely to be built which will increase competition and lower the value of some
of the Company's non-rate regulated electric generation assets.
The regulatory environment of the wholesale energy markets in which the
Company invests may adversely affect the competitive conditions of those
markets. In several regions, notably California and in the PJM Power Pool Region
(in the Mid-Atlantic region of the United States), the independent system
operators have chosen to rely on price caps and market redesigns as a way of
minimizing market volatility.
The results of operations of the Company's non-rate regulated generation
assets are also affected by the weather conditions in the relevant wholesale
energy markets. Extreme seasonal weather conditions typically increase the
demand for wholesale energy. Conversely, mild weather conditions typically have
the opposite effect. In some regions, especially California, weather conditions
associated with hydroelectric generation resources such as rainfall and snowpack
can significantly influence market prices for electric power by increasing or
decreasing the availability and timing of hydro-based generation which is
imported into the California market.
Competition for acquisition of international and domestic non-rate
regulated power projects is intense. The Company competes 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 larger
portfolios of projects. Competitive factors relevant to the non-utility power
industry include financial resources, access to non-recourse funding and
regulatory factors.
Reliant Energy Services competes for sales in its natural gas, electric
power and other energy derivatives trading and marketing business with other
energy 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, wholesale energy suppliers and transporters to seek financial
guarantees and other assurances that
46
49
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.
Natural Gas Distribution. Natural Gas Distribution competes primarily with
alternate energy sources such as electricity and other fuel sources. 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.
Interstate Pipelines. The Interstate Pipelines 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 Pipelines
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 Pipelines and the level of
competition for transport and storage services.
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.
INDEXED DEBT SECURITIES (ACES AND ZENS) AND TIME WARNER INVESTMENT
For information on Reliant Energy's indexed debt securities and its
investment in TW Common, see "Quantitative and Qualitative Disclosures About
Market Risk" in Item 7A of this Report and Note 8 to the Company's Consolidated
Financial Statements.
IMPACT OF THE YEAR 2000 ISSUE AND OTHER SYSTEM IMPLEMENTATION ISSUES
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. The evaluation of Year 2000 issues included those related to
significant customers, key vendors, service suppliers and other parties material
to the Company's operations.
Remediation and testing of all systems and equipment were completed during
1999. The Company did not experience any Year 2000 problems that significantly
affected the operations of the Company. The Company will continue to monitor and
assess potential future problems. Total direct costs of resolving the Year 2000
issue with respect to the Company were $29 million.
The Company is in the process of implementing SAP America, Inc.'s (SAP)
proprietary R/3 enterprise software. Although the implementation of the SAP
system had 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, March 1999 and September 1999, and it is expected that the final portion
of the SAP system will be fully implemented by the fourth quarter of 2002. The
cost of implementing the SAP system is currently estimated to be approximately
$237 million, inclusive of internal costs. As of December 31, 1999, $192 million
has been spent on the implementation.
47
50
ENTRY INTO THE EUROPEAN MARKET
Reliant Energy Europe owns, operates and sells power from generation
facilities in the Netherlands and plans to participate in the emerging wholesale
energy trading and marketing industry in the Netherlands and other countries in
Europe. Reliant Energy expects that the Dutch electric industry will undergo
change in response to market deregulation in 2001. These expected changes
include the anticipated expiration of certain transition agreements which have
governed the basic tariff rates that UNA and other generators have charged their
customers. Based on current forecasts and other assumptions, the revenues of UNA
could decline significantly from 1999 revenues after 2000.
One of the factors that could have a significant impact on the Dutch energy
industry, including the operations of UNA, is the ultimate resolution of
stranded cost issues in the Netherlands. The Dutch government is currently
seeking to establish a transitional regime in order to solve the problem of
stranded costs, which relate primarily to investments and contracts entered into
by SEP and certain licensed generators prior to the liberalization of the
market. SEP is owned in equal shares by each of the four large Dutch generating
companies, including UNA.
In connection with the acquisition of UNA, the selling shareholders of UNA
agreed to indemnify UNA for certain stranded costs in an amount not to exceed
NLG 1.4 billion (approximately $639 million based on an exchange rate of 2.19
NLG per U.S. dollar as of December 31, 1999), which may be increased in certain
circumstances at the option of the Company up to NLG 1.9 billion (approximately
$868 million). Of the total consideration paid by the Company for the shares of
UNA, NLG 900 million (approximately $411 million) has been placed by the selling
shareholders in an escrow account to secure the indemnity obligations. Although
Reliant Energy believes that the indemnity provision will be sufficient to cover
UNA's ultimate share of any stranded cost obligation, this belief is based on
numerous assumptions regarding the ultimate outcome and timing of the resolution
of the stranded cost issue, the existing shareholders timely performance of
their obligations under the indemnity arrangement, and the amount of stranded
costs which at present is not determinable.
The Dutch government is expected to propose a legislative initiative
regarding stranded costs to the Dutch cabinet in March 2000. The proposed
legislation will be sent to the Dutch council of state for review. It is not
anticipated that the legislation will be reviewed by parliament until late in
the summer of 2000.
For information about the Company's exposure through its investment in
Reliant Energy Europe to losses resulting from fluctuations in currency rates,
see "Quantitative and Qualitative Disclosures About Market Risk" in Item 7A of
this Form 10-K.
RISK OF OPERATIONS IN EMERGING MARKETS
Reliant Energy Latin America's 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 Latin American 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 owns
11.78% of the stock of Light Servicos de Eletricidade S.A. (Light) and, through
its investment in Light, a 9.2% interest in the stock of Metropolitana
Electricidade de Sao Paulo S.A. (Metropolitana). As of December 31, 1999 and
1998, Light and Metropolitana had total borrowings of $2.9 billion and $3.2
billion, respectively, denominated in non-local currencies. During the first
quarter of 1999, the Brazilian real was devalued and allowed to float against
other major currencies. The effects of devaluation on the non-local currency
denominated borrowings caused the Company to record an after-tax charge for the
year ended December 31, 1999 of $102 million as a result of foreign currency
transaction losses recorded by both Light and Metropolitana in such periods. For
additional information regarding the effect of the devaluation of the Brazilian
real, see Note 7(a) in the Company's Consolidated Financial Statements.
48
51
Light's and Metropolitana's tariff adjustment mechanisms are not directly
indexed to the U.S. dollar or other non-local currencies. To partially offset
the devaluation of the Brazilian real, and the resulting increased operating
costs and inflation, Light and Metropolitana received tariff rate increases of
16% and 21%, respectively, which were phased in during June and July 1999. Light
also received its annual rate adjustment in November 1999 resulting in a tariff
rate increase of 11%. The Company is pursuing additional tariff increases to
mitigate the impact of the devaluation; however, there can be no assurance that
such adjustments will be timely or that they will permit substantial recovery of
the impact of the devaluation.
Certain of Reliant Energy Latin America's other foreign electric
distribution companies have incurred U.S. dollar and other non-local currency
indebtedness (approximately $600 million at December 31, 1999). 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 Projected Capital Resources. 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. For a discussion of the Company's anticipated capital
contributions in 2000, see "-- Liquidity and Capital Resources -- Future Sources
and Uses of Cash Flows -- Reliant Energy Latin America Capital Contributions and
Advances." In 2000, $1.6 billion of debt obligations of Light and Metropolitana
will mature. The availability or terms of refinancing such debt cannot be
assured. Currency fluctuation and instability affecting Latin America may also
adversely affect the Company's ability to refinance its equity investments with
debt.
ENVIRONMENTAL EXPENDITURES
The Company is subject to numerous environmental laws and regulations,
which require it 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). NOx reduction costs
incurred by Electric Operations generating units in the Houston, Texas area
totaled approximately $7 million in 1999 and $7 million in 1998. The Texas
Natural Resources Conservation Commission (TNRCC) is currently considering
additional NOx reduction requirements for electric generating units and other
industrial sources located in the Houston metropolitan area and the eastern half
of Texas as a means to attain the Clean Air Act standard for ozone. Although the
magnitude and timing of these requirements will not be established by the TNRCC
until November, 2000, NOx reductions approaching 90% of the emissions level are
anticipated. Expenditures for NOx controls on Electric Operations' generating
units have been estimated at $500 million to $600 million during the period 2000
through 2003, with an estimated $80 million to be incurred during 2000. In
addition, the Legislation created a program mandating air emissions reductions
for certain generating facilities of Electric Operations. The Legislation
provides for stranded cost recovery for costs associated with this obligation
incurred before May 1, 2003. For further information regarding the Legislation,
see Note 3 to the Company's Consolidated Financial Statements.
49
52
Site Remediation Expenditures. From time to time the Company has received
notices from regulatory authorities or others regarding its status as a
potentially responsible party in connection with sites found to require
remediation due to the presence of environmental contaminants. Based on
currently available information, Reliant Energy believes that remediation costs
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 Reliant Energy's estimates. For
information about specific sites that are the subject of remediation claims, see
Note 14(h) to the Company's Consolidated Financial Statements and Note 8(d) to
Resources' Consolidated Financial Statements.
Mercury Contamination. Like other natural gas pipelines, the Company's
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 the Company has conducted remediation at sites found to be
contaminated. Although the Company 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 the Company and others in the natural
gas industry to date and on the current regulations regarding remediation of
such sites, the Company believes 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, see Notes 3, 4 and 14 to the Company's Consolidated
Financial Statements and Note 8 to Resources' Consolidated Financial Statements.
50
53
LIQUIDITY AND CAPITAL RESOURCES
COMPANY CONSOLIDATED CAPITAL REQUIREMENTS
The liquidity and capital requirements of the Company are affected
primarily by capital programs and debt service requirements. Expenditures in the
table reflect only expenditures made or to be made under existing contractual
commitments as of December 31, 1999. The Company expects to continue to
participate as a bidder in future acquisitions of independent power projects and
privatizations of generation facilities. Such capital requirements are expected
to be met with excess cash flows from operations, the proceeds of project
financings and the proceeds of Company borrowings. Additional capital
expenditures are dependent upon the nature and extent of future project
commitments (some of which may be substantial). The capital requirements for
1999 were, and as estimated for 2000 through 2004 are, as follows (in millions):
1999 2000 (1) 2001 2002 2003 2004
------- ------- ------- ------- ------- -------
Electric Operations (with nuclear fuel) (2) .............. $ 573 $ 722 $ 885 $ 520 $ 524 $ 528
Natural Gas Distribution ................................. 206 197 161 162 162 165
Interstate Pipelines ..................................... 30 20 17 17 17 17
Wholesale Energy (2)(3) .................................. 530 720 225 265 192 126
Reliant Energy Europe .................................... 834 980 5 5 5 5
Reliant Energy Latin America ............................. 93
Corporate ................................................ 90 86 87 84 86 104
Payments of long-term debt, sinking fund requirements
and minimum capital lease (1) ......................... 936 409 773 670 741 58
------- ------- ------- ------- ------- -------
Total ............................................... $ 3,292 $ 3,134 $ 2,153 $ 1,723 $ 1,727 $ 1,003
======= ======= ======= ======= ======= =======
- -------
(1) Excludes the ACES (see Note 8 to the Company's Consolidated Financial
Statements) as the ACES may be settled with the Company's investment in TW
Common.
(2) Beginning in 2002, capital requirements for current generation operations
of Reliant Energy HL&P are included in Wholesale Energy rather than in
Electric Operations.
(3) Amounts do not reflect capital requirements related to the $2.1 billion
cost of the pending Sithe power generating assets acquisition described in
Note 19 to the Company's Consolidated Financial Statements.
The net cash provided by/used in operating, investing and financing
activities for the years ended December 31, 1999, 1998 and 1997 is as follows
(in millions):
YEAR ENDED DECEMBER 31,
---------------------------------------
1999 1998 1997
--------- --------- ---------
Cash provided by (used in):
Operating activities ........... $ 1,162 $ 1,425 $ 1,111
Investing activities ........... (2,897) (1,230) (1,981)
Financing activities ........... 1,794 (218) 914
Net cash provided by operations in 1999 decreased $263 million compared to
1998 reflecting a $142 million federal tax refund received in 1998 and other
changes in working capital. Net cash provided by operations in 1998 increased
$314 million over 1997 primarily due to incremental cash flow provided by the
business segments purchased in the Resources acquisition, increased sales at
Electric Operations due to unusually hot weather during the second and third
quarters of 1998, and the receipt of a federal tax refund in 1998.
Net cash used in investing activities increased $1.7 billion in 1999
compared to 1998 primarily due to the cash portion of the purchase price for 52%
of UNA totaling $833 million, the purchase of 9.2 million shares of TW Common
for $537 million, increased capital expenditures and the sale of an investment
in an Argentine electric distribution
51
54
company in 1998 partially offset by equity investments made in 1998 by Reliant
Energy Latin America. Net cash used in investing activities decreased $751
million in 1998 compared to 1997 due primarily to the Resources acquisition in
1997.
Cash flows provided by financing activities increased approximately $2.0
billion in 1999 primarily due to cash received from short-term borrowings, the
net issuance of long-term debt and the issuance of trust preferred securities
aggregating $2.3 billion (see Notes 10 and 11 to the Company's Consolidated
Financial Statements), partially offset by $91 million of purchases of Reliant
Energy's common stock. The net borrowings incurred during 1999 were utilized to
purchase TW Common, to complete the first and second phases of the acquisition
of UNA, to support increased capital expenditures, and to fund the working
capital requirements of the Company. Cash flows provided by financing activities
decreased approximately $1.1 billion in 1998 compared to 1997 primarily due to a
decline in short-term borrowings of $1.1 billion. The net borrowings incurred
during 1997 were utilized primarily to finance a portion of the cost of the
Resources acquisition.
FUTURE SOURCES AND USES OF CASH FLOWS
Credit Facilities. As of December 31, 1999, the Company had credit
facilities, including facilities of various financing subsidiaries, Resources
and UNA, which provide for an aggregate of $3.7 billion in committed credit. As
of December 31, 1999, $2.7 billion was outstanding under these facilities,
including commercial paper of $1.8 billion. Unused credit facilities totaled
$1.0 billion as of December 31, 1999. For further discussion, see Note 10(a) to
the Company's Consolidated Financial Statements. In February 2000, a financing
subsidiary of the Company borrowed $500 million under a $650 million revolving
credit facility that was established in February 2000 and will terminate on
April 30, 2000. Proceeds were used by the financing subsidiary to purchase
Series G Preference Stock of Reliant Energy. The Company used the proceeds from
the sale of Preference Stock for general corporate purposes, including the
repayment of indebtedness. In addition, in March 2000, the Company borrowed $150
million under a revolving credit facility that was established in February 2000
and will terminate on May 31, 2000. The Company used the proceeds from the
borrowing for general corporate purposes, including the repayment of
indebtedness.
Shelf Registrations. At December 31, 1999, the Company had shelf
registration statements providing for the issuance of $230 million aggregate
liquidation value of its preferred stock, $580 million aggregate principal
amount of its debt securities and $125 million of trust preferred securities and
related junior subordinated debt securities (see Note 11 to the Company's
consolidated financial statements). In addition, the Company has a shelf
registration for 15 million shares of common stock which would have been worth
approximately $343 million as of December 31, 1999 based on the closing price of
the common stock as of such date.
Money Fund. Reliant Energy has a "money fund" through which it and certain
of its subsidiaries can borrow or invest on a short-term basis. Funding needs
are aggregated and borrowing or investing is based on the net cash position. The
money fund's net funding requirements are generally met with commercial paper.
Securitization. Reliant Energy HL&P has filed an application with the Texas
Utility Commission requesting a financing order authorizing the issuance by a
special purpose entity organized by the Company, pursuant to the Legislation, of
transition bonds relating to Reliant Energy HL&P's generation related regulatory
assets. The Company estimates that approximately $750 million of transition
bonds will be authorized by the Texas Utility Commission. Payments on the
transition bonds will be made out of funds derived from non-bypassable
transition charges assessed to Reliant Energy HL&P's transmission and
distribution customers. The offering and sale of the transition bonds will be
registered under the Securities Act of 1933 and, absent any appeals, are
expected to be consummated in the second or third quarter of 2000. The
transition bonds will only be offered and sold by means of a prospectus. This
report does not constitute an offer to sell or the solicitation of an offer to
buy nor will there by any sale of the transition bonds in any state in which
such offer, solicitation or sale would be unlawful prior to registration or
qualification under the securities laws of such state.
Acquisition of UNA. The Company completed the first and second phases of
the acquisition of 52% of UNA in the fourth quarter of 1999 which consisted of
total consideration of $833 million in cash and $426 million in a five-year
promissory note to UNA. The promissory note must be prepaid in certain
circumstances. On March 1, 2000, the remaining 48% of the UNA shares were
purchased for approximately $975 million in cash. The total purchase price,
payable in NLG, of
52
55
approximately $2.4 billion includes the $426 million promissory note to UNA and
assumes an exchange rate of 2.0565 NLG per U.S. dollar (the exchange rate on
October 7, 1999). Funds for the March 1, 2000 obligation were obtained, in part,
from a Euro 600 million (approximately $596 million) three-year term loan
facility established in February 2000.
Acquisition of Sithe Assets. In February 2000, Power Generation signed a
definitive agreement to purchase from Sithe Energies, Inc. non-rate regulated
power generating assets and sites located in Pennsylvania, New Jersey and
Maryland having a net generating capacity of more than 4,200 MW for an aggregate
purchase price of approximately $2.1 billion, subject to certain adjustments.
The acquisition is expected to close in the second quarter of 2000 subject to
obtaining certain regulatory approvals and satisfying other closing conditions.
The acquisition will be accounted for as a purchase. The Company has executed
bank commitment letters and expects to enter into a bridge loan prior to
obtaining permanent financing. The permanent financing is likely to include an
operating lease covering a portion of the generating assets.
Treasury Stock Purchases. As of December 31, 1999, the Company was
authorized under its common stock repurchase program to purchase an additional
$298 million of its common stock. The Company's purchases under its repurchase
program depend on market conditions, might not be announced in advance and may
be made in open market or privately negotiated transactions. For information on
the Company's purchases since December 31, 1999, see Note 19 to the Company's
Consolidated Financial Statements.
Reliant Energy Latin America Capital Contributions and Advances. Reliant
Energy Latin America expects to make capital contributions or advances in 2000
totaling approximately $108 million as a result of debt service payments at
certain of its holding companies. It is expected that part of these capital
contributions will be paid from a return of capital from one of its investments,
dividends from certain of its operating companies, proceeds from the sale of
certain of its investments and from additional capital contributions from
Reliant Energy.
Channelview Project. The Company's 780 MW gas-fired cogeneration plant
located in Channelview, Texas, which is currently under construction, is
expected to cost $463 million, $71 million of which had been incurred as of
December 31, 1999. The project has been financed through obtaining commitments
for an equity bridge loan of $92 million and a non-recourse loan of $369
million.
Other Sources/Uses of Cash. The Company participates from time to time in
competitive bids and the development of new projects for generating and
distribution assets. 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 develops or acquires new businesses and
assets, supplement its available cash resources by seeking funds in the equity
or debt markets.
NEW ACCOUNTING ISSUES
Effective January 1, 2001, the Company is required to adopt Statement of
Financial Accounting Standards No. 133, "Accounting For Derivative Instruments
and Hedging Activities," as amended (SFAS No. 133), which establishes accounting
and reporting standards for derivative instruments, including certain hedging
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 the adoption of SFAS No. 133 on its consolidated
financial statements.
53
56
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
INTEREST RATE RISK
The Company has long-term debt, Company obligated mandatorily redeemable
preferred securities of subsidiary trusts holding solely junior subordinated
debentures of the Company (Trust Preferred Securities), securities held in the
Company's nuclear decommissioning trust, bank facilities, certain lease
obligations and interest rate swaps which subject the Company to the risk of
loss associated with movements in market interest rates.
At December 31, 1999, the Company had issued fixed-rate debt (excluding
indexed debt securities) and Trust Preferred Securities aggregating $5.8 billion
in principal amount and having a fair value of $5.6 billion. These instruments
are fixed-rate and, therefore, do not expose the Company to the risk of loss in
earnings due to changes in market interest rates (see Notes 10 and 11 to the
Company's Consolidated Financial Statements). However, the fair value of these
instruments would increase by approximately $305 million if interest rates were
to decline by 10% from their levels at December 31, 1999. In general, such an
increase in fair value would impact earnings and cash flows only if the Company
were to reacquire all or a portion of these instruments in the open market prior
to their maturity.
The Company's floating-rate obligations aggregated $3.1 billion at December
31, 1999 (see Note 10 to the Company's Consolidated Financial Statements),
inclusive of (i) amounts borrowed under short-term and long-term credit
facilities of the Company (including the issuance of commercial paper supported
by such facilities), (ii) borrowings underlying a receivables facility and (iii)
amounts subject to a master leasing agreement under which lease payments vary
depending on short-term interest rates. These floating-rate obligations expose
the Company 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, 1999 levels, the Company's consolidated interest
expense and expense under operating leases would increase by a total of
approximately $1.6 million each month in which such increase continued.
As discussed in Notes 1(l) and 6(c) 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 $145 million as of December 31, 1999, of which
approximately 40% 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, 1999, 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. 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. For further discussion regarding the
recovery of decommissioning costs pursuant to the Legislation, see Note 3 to the
Consolidated Financial Statements.
As discussed in Note 1(l) to the Company's Consolidated Financial
Statements, UNA holds fixed-rate debt securities, which had an estimated fair
value of $133 million as of December 31, 1999, that subject the Company to risk
of loss of fair value and earnings with movements in market interest rates. If
interest rates were to increase by 10% from their levels at December 31, 1999,
the decrease in fair value and loss in earnings from this investment would not
be material to the Company.
The Company has entered into interest rate swaps for the purpose of
decreasing the amount of debt subject to interest rate fluctuations. At December
31, 1999, these interest rate swaps had an aggregate notional amount of $64
million and the cost to terminate would not result in a material loss in
earnings and cash flows to the Company (see Note 5 to the Company's Consolidated
Financial Statements). An increase of 10% in the December 31, 1999 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 earnings and cash flows only if all or a portion of the swap
instruments were terminated prior to their expiration.
54
57
As discussed in Note 10(b) to the Company's Consolidated Financial
Statements, in November 1998, 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, 1999, the Company
could terminate the option at a cost of $11 million. A decrease of 10% in the
December 31, 1999 level of interest rates would increase the cost of termination
of the option by approximately $5 million.
EQUITY MARKET RISK
As discussed in Note 8 to the Company's Consolidated Financial Statements,
the Company owns approximately 55 million shares of TW Common, of which
approximately 38 million and 17 million shares are held by the Company to
facilitate its ability to meet its obligations under the ACES and ZENS,
respectively. Unrealized gains and losses resulting from changes in the market
value of the Company's TW Common are recorded in the Consolidated Statement of
Operations. Increases in the market value of TW Common result in an increase in
the liability for the ZENS and ACES and are recorded as a non-cash expense. Such
non-cash expense will be offset by an unrealized gain on the Company's TW Common
investment. However, if the market value of TW Common declines below $58.25, the
ZENS payment obligation will not decline below its original principal amount. As
of December 31, 1999, the market value of TW Common was $72.31 per share. A
decrease of 10% from the December 31, 1999 market value of TW Common would not
result in a loss. As of March 1, 2000, the market value of TW Common was $84.38
per share. In addition, the Company has a $14 million investment in Cisco
Systems, Inc. as of December 31, 1999, which is classified as trading under SFAS
No. 115, "Accounting for Certain Investments in Debt and Equity Securities"(SFAS
No. 115). In January 2000, the Company entered into financial instruments (a put
option and a call option) to manage price risks related to the Company's
investment in Cisco Systems, Inc. A decline in the market value of this
investment would not materially impact the Company's earnings and cash flows.
The Company also has a $9 million investment in Itron, Inc. (Itron) which is
classified as "available for sale" under SFAS No. 115. The Itron investment
exposes the Company to losses in the fair value of Itron common stock. A 10%
decline in the market value per share of Itron common stock from the December
31, 1999 levels would not result in a material loss in fair value to the
Company.
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, 1999. 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, 1999, 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 discussed above under "--Interest Rate Risk."
FOREIGN CURRENCY EXCHANGE RATE RISK
As further described in "Certain Factors Affecting Future Earnings of the
Company -- Risks of Operations in Emerging Markets" in Item 7 of this Form 10-K,
the Company has investments in electric generation and distribution facilities
in Latin America with a substantial portion accounted for under the equity
method. In addition, as further discussed in Note 2 of the Company's
Consolidated Financial Statements, during the fourth quarter of 1999, the
Company completed the first and second phases of the acquisition of 52% of the
shares UNA, a Dutch power generation company and completed the final phase of
the acquisition on March 1, 2000. These foreign operations 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. The Company has
entered into foreign currency swaps and has issued Euro denominated debt to
hedge its net investment in UNA. Changes in the value of the swap and debt are
recorded as foreign currency translation adjustments as a component of
stockholders' equity. For further discussion of the accounting for foreign
currency adjustments, see Note 1(m) in the Company's Consolidated Financial
Statements. The cumulative translation loss of $77 million, recorded as of
December 31, 1999, will be realized as a loss in earnings and cash flows only
upon the disposition of the related investments. The cumulative translation loss
was $34 million as of
55
58
December 31, 1998. The increase in cumulative translation loss from December 31,
1998 to December 31, 1999, was primarily due to the impact of devaluation of the
Brazilian real on the Company's investments in Light and Metropolitana.
In addition, certain of Reliant Energy Latin America'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, 1999, Light and Metropolitana of which the
Company owns 11.78% and 9.2%, respectively, had total borrowings of
approximately $2.9 billion denominated in non-local currencies. As described in
Note 7 to the Company's Consolidated Financial Statements, in 1999 the Company
reported a $102 million (after-tax) charge to net income and a $43 million
charge to other comprehensive income, due to the devaluation of the Brazilian
real. The charge to net income reflects increases in the liabilities at Light
and Metropolitana for their non-local currency denominated borrowings using the
exchange rate in effect at December 31, 1999 and a monthly weighted average
exchange rate for the year then ended. The charge to other comprehensive income
reflects the translation effect on the local currency denominated net assets
underlying the Company's investment in Light. As of December 31, 1999, the
Brazilian real exchange rate was 1.79 per U.S. dollar. An increase of 10% from
the December 31, 1999 exchange rate would result in the Company recording an
additional charge of $20 million and $23 million to net income and other
comprehensive income, respectively. As of March 1, 2000, the Brazilian real
exchange rate was 1.77 per U.S. dollar.
The Company attempts to manage and mitigate this foreign currency risk by
balancing the 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 its financial plans. In addition, where possible, Reliant Energy
Latin America 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 5 to the Company's Consolidated Financial
Statements, the Company utilizes a variety of derivative financial instruments
(Derivatives), including swaps, over-the-counter options 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 and transmission, the Company enters 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, transportation and transmission 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 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.
With respect to the Energy Derivatives (other than Trading Derivatives)
held by the Company as of December 31, 1999, an increase of 10% in the market
prices of natural gas and electric power from year-end levels would have
decreased the fair value of these instruments by approximately $12 million. As
of December 31, 1998, a decrease of 10% in the market prices of natural gas and
electric power from year-end levels would have decreased the fair value of these
instruments by approximately $3 million.
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 physical purchases and sales of natural gas and
electric power to which the hedges relate. 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
56
59
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,
weather derivatives, physical forwards, swaps, options and exchange-traded
futures and options, the Company is exposed to losses in fair value due to
changes in the price and volatility of the underlying derivatives. During the
years ended December 31, 1999 and 1998, the highest, lowest and average monthly
value-at-risk in the Trading Derivative portfolio was less than $10 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 delta approximation for option positions.
The Company has established a Risk Oversight Committee comprised of
corporate and business segment officers that oversees all commodity price and
credit risk activities, including derivative trading and hedging activities
discussed above. The committee's duties are to establish the Company's commodity
risk policies, allocate risk capital within limits established by the Company's
board of directors, approve trading of new products and commodities, monitor
risk positions and ensure compliance with the Company's risk management policies
and procedures and the trading limits established by the Company's board of
directors.
57
60
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA OF THE COMPANY.
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED INCOME
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
YEAR ENDED DECEMBER 31,
----------------------------------------------
1999 1998 1997
------------ ------------ ------------
REVENUES ........................................................... $ 15,302,810 $ 11,488,464 $ 6,878,225
EXPENSES:
Fuel and cost of gas sold ....................................... 6,748,325 4,840,505 2,865,701
Purchased power ................................................. 4,137,414 2,215,049 698,823
Operation and maintenance ....................................... 1,821,471 1,625,343 1,218,579
Taxes other than income taxes ................................... 443,964 471,656 374,702
Depreciation and amortization ................................... 911,122 870,093 665,374
------------ ------------ ------------
Total ....................................................... 14,062,296 10,022,646 5,823,179
------------ ------------ ------------
OPERATING INCOME ................................................... 1,240,514 1,465,818 1,055,046
------------ ------------ ------------
OTHER INCOME (EXPENSE):
Unrealized gain in Time Warner investment ....................... 2,452,406
Unrealized loss on indexed debt securities ...................... (629,523) (1,176,211) (121,402)
Time Warner dividend income ..................................... 25,770 41,250 41,340
Interest income - IRS refund .................................... 56,269
Other, net ...................................................... 38,375 36,421 19,801
------------ ------------ ------------
Total ....................................................... 1,887,028 (1,098,540) (3,992)
------------ ------------ ------------
INTEREST AND OTHER CHARGES:
Interest ........................................................ 511,474 509,601 395,085
Distribution on trust preferred securities ...................... 51,220 29,201 26,230
Preferred dividends of subsidiary ............................... 2,255
------------ ------------ ------------
Total ....................................................... 562,694 538,802 423,570
------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES, EXTRAORDINARY ITEM AND
PREFERRED DIVIDENDS ............................................. 2,564,848 (171,524) 627,484
Income Tax Expense (Benefit) ....................................... 899,117 (30,432) 206,374
------------ ------------ ------------
INCOME (LOSS) BEFORE EXTRAORDINARY ITEM AND PREFERRED DIVIDENDS .... 1,665,731 (141,092) 421,110
Extraordinary Item, net of income tax of $98,679 ................... 183,261
------------ ------------ ------------
INCOME (LOSS) BEFORE PREFERRED DIVIDENDS ........................... 1,482,470 (141,092) 421,110
Preferred Dividends ................................................ 389 390 162
------------ ------------ ------------
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS .............. $ 1,482,081 $ (141,482) $ 420,948
============ ============ ============
BASIC EARNINGS (LOSS) PER SHARE:
Income (Loss) Before Extraordinary Item ......................... $ 5.84 $ (.50) $ 1.66
============ ============ ============
Extraordinary Item .............................................. $ (.64) $ $
============ ============ ============
Net Income (Loss) Attributable to Common Stockholders ........... $ 5.20 $ (.50) $ 1.66
============ ============ ============
DILUTED EARNINGS (LOSS) PER SHARE:
Income (Loss) Before Extraordinary Item ......................... $ 5.82 $ (.50) $ 1.66
============ ============ ============
Extraordinary Item .............................................. $ (.64) $ $
============ ============ ============
Net Income (Loss) Attributable to Common Stockholders ........... $ 5.18 $ (.50) $ 1.66
============ ============ ============
See Notes to the Company's Consolidated Financial Statements
58
61
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
(THOUSANDS OF DOLLARS)
YEAR ENDED DECEMBER 31,
----------------------------------------------
1999 1998 1997
------------ ------------ ------------
Net income (loss) attributable to common stockholders .......... $ 1,482,081 $ (141,482) $ 420,948
Foreign currency translation adjustments (net of tax of $23,143,
$17,656 and $247) ............................................ (42,979) (32,790) (458)
Unrealized loss on available for sale securities (net of tax of
$373, $5,877 and $1,181) ..................................... (1,224) (10,370) (1,897)
------------ ------------ ------------
COMPREHENSIVE INCOME (LOSS) ....................................... $ 1,437,878 $ (184,642) $ 418,593
============ ============ ============
See Notes to the Company's Consolidated Financial Statements
59
62
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF DOLLARS)
DECEMBER 31,
----------------------------
1999 1998
------------ ------------
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ............................................... $ 89,078 $ 29,673
Investment in Time Warner common stock .................................. 3,979,461
Accounts receivable - net ............................................... 1,104,640 726,377
Accrued unbilled revenues ............................................... 172,629 175,515
Fuel stock and petroleum products ....................................... 152,292 211,750
Materials and supplies, at average cost ................................. 188,167 171,998
Price risk management assets ............................................ 435,336 265,203
Prepayments and other current assets .................................... 131,666 88,655
------------ ------------
Total current assets .................................................. 6,253,269 1,669,171
------------ ------------
PROPERTY, PLANT AND EQUIPMENT - NET ....................................... 13,267,395 11,503,114
------------ ------------
OTHER ASSETS:
Goodwill and other intangibles - net .................................... 3,034,361 2,098,890
Equity investments and advances to unconsolidated subsidiaries .......... 1,022,210 1,051,600
Investment in Time Warner preferred stock ............................... 990,000
Regulatory assets ....................................................... 1,739,507 1,313,362
Price risk management assets ............................................ 148,722 21,414
Deferred debits ......................................................... 755,472 490,971
------------ ------------
Total other assets .................................................... 6,700,272 5,966,237
------------ ------------
Total Assets .......................................................... $ 26,220,936 $ 19,138,522
============ ============
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES:
Short-term borrowings ................................................... $ 2,879,211 $ 1,812,739
Current portion of long-term debt ....................................... 4,382,136 397,454
Accounts payable ........................................................ 1,036,839 807,977
Taxes accrued ........................................................... 227,058 252,581
Interest accrued ........................................................ 116,274 115,201
Dividends declared ...................................................... 110,811 111,058
Price risk management liabilities ....................................... 424,324 227,652
Accumulated deferred income taxes ....................................... 415,591
Business purchase obligation ............................................ 431,570
Other ................................................................... 360,109 346,280
------------ ------------
Total current liabilities ............................................. 10,383,923 4,070,942
------------ ------------
DEFERRED CREDITS:
Accumulated deferred income taxes ....................................... 2,451,619 2,364,036
Unamortized investment tax credit ....................................... 270,243 328,949
Price risk management liabilities ....................................... 117,437 40,532
Benefit obligations ..................................................... 400,849 378,747
Business purchase obligation ............................................ 596,303
Other ................................................................... 1,027,648 490,468
------------ ------------
Total deferred credits ................................................ 4,864,099 3,602,732
------------ ------------
LONG-TERM DEBT ............................................................ 4,961,310 6,800,748
------------ ------------
COMMITMENTS AND CONTINGENCIES (NOTE 14)
COMPANY OBLIGATED MANDATORILY REDEEMABLE PREFERRED SECURITIES OF SUBSIDIARY
TRUSTS HOLDING SOLELY JUNIOR SUBORDINATED DEBENTURES OF THE COMPANY ..... 705,272 342,232
------------ ------------
STOCKHOLDERS' EQUITY ...................................................... 5,306,332 4,321,868
------------ ------------
Total Liabilities and Stockholders' Equity ............................ $ 26,220,936 $ 19,138,522
============ ============
See Notes to the Company's Consolidated Financial Statements
60
63
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED CASH FLOWS
(THOUSANDS OF DOLLARS)
YEAR ENDED DECEMBER 31,
----------------------------------------------
1999 1998 1997
------------ ------------ ------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) attributable to common stockholders .......... $ 1,482,081 $ (141,482) $ 420,948
Adjustments to reconcile net income (loss) to net cash
provided by operating activities:
Depreciation and amortization ................................ 911,122 870,093 665,374
Deferred income taxes ........................................ 601,627 (423,904) 35,523
Investment tax credit ........................................ (58,706) (20,123) (19,777)
Unrealized gain on Time Warner investment .................... (2,452,406)
Unrealized loss on indexed debt securities ................... 629,523 1,176,211 121,402
Extraordinary item ........................................... 183,261
Undistributed earnings of unconsolidated subsidiaries ........ 28,308 (27,350) (3,142)
Changes in other assets and liabilities:
Accounts receivable - net .................................. (333,195) 266,938 (436,580)
Inventories ................................................ 51,576 (121,793) 55,111
Accounts payable ........................................... 185,710 (92,652) 191,840
Other - net ................................................ (67,236) (60,579) 80,060
------------ ------------ ------------
Net cash provided by operating activities ............... 1,161,665 1,425,359 1,110,759
------------ ------------ ------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures ........................................... (1,179,466) (743,455) (328,724)
Investment in Time Warner securities ........................... (537,055)
Business acquisitions, net of cash acquired .................... (871,168) (1,422,672)
Acquisition of non-rate regulated electric power plants ........ (188,832) (292,398)
Investments and advances to unconsolidated subsidiaries ........ (116,076) (445,042) (234,852)
Sale of equity investments in foreign electric system
projects ................................................ 242,744
Other - net .................................................... (4,288) 8,375 4,795
------------ ------------ ------------
Net cash used in investing activities ................... (2,896,885) (1,229,776) (1,981,453)
------------ ------------ ------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt - net ............................. 2,032,386 1,267,107 1,136,516
Payments of long-term debt ..................................... (935,908) (733,114) (780,186)
Proceeds from sale of trust preferred securities - net ......... 362,994 340,785
Increase (decrease) in short-term borrowings - net ............. 822,868 (312,217) 787,084
Redemption of preferred stock .................................. (153,628)
Payment of common stock dividends .............................. (427,255) (426,265) (405,288)
Purchase of treasury stock ..................................... (90,708)
Other - net .................................................... 30,248 (13,133) (10,878)
------------ ------------ ------------
Net cash provided by (used in) financing activities .... 1,794,625 (217,622) 914,405
------------ ------------ ------------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS .............. 59,405 (22,039) 43,711
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD .................. 29,673 51,712 8,001
------------ ------------ ------------
CASH AND CASH EQUIVALENTS AT END OF PERIOD ........................ $ 89,078 $ 29,673 $ 51,712
============ ============ ============
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash Payments:
Interest (net of amounts capitalized) .......................... $ 517,897 $ 502,889 $ 414,467
Income taxes ................................................... 401,703 484,376 171,539
See Notes to the Company's Consolidated Financial Statements
61
64
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED STOCKHOLDERS' EQUITY
(THOUSANDS OF DOLLARS AND SHARES)
1999 1998 1997
-------------------------- -------------------------- --------------------------
SHARES AMOUNT SHARES AMOUNT SHARES AMOUNT
----------- ----------- ----------- ----------- ----------- -----------
PREFERENCE STOCK, NONE OUTSTANDING ...
=========== ----------- =========== ----------- =========== -----------
CUMULATIVE PREFERRED STOCK
Balance, beginning of year ........ 97 $ 9,740 97 $ 9,740 1,347 $ 135,179
Redemption of preferred stock ..... (1,250) (125,439)
----------- ----------- ----------- ----------- ----------- -----------
Balance, end of year .............. 97 9,740 97 9,740 97 9,740
=========== ----------- =========== ----------- =========== -----------
COMMON STOCK, NO PAR; AUTHORIZED
700,000,000 SHARES
Balance, beginning of year ........ 296,271 3,136,826 295,357 3,112,098 262,748 2,447,117
Issuances related to benefit
and investment plans ............ 1,341 46,062 914 24,734 811 16,737
Issuances of common stock in
business acquisition ............ 47,840 1,011,924
Treasury shares retired ........... (16,042) (361,196)
Other ............................. (137) (6) (2,484)
----------- ----------- ----------- ----------- ----------- -----------
Balance, end of year .............. 297,612 3,182,751 296,271 3,136,826 295,357 3,112,098
=========== ----------- =========== ----------- =========== -----------
TREASURY STOCK
Balance, beginning of year ........ (103) (2,384) (93) (2,066) (16,042) (361,196)
Shares acquired ................... (3,524) (90,708)
Treasury stock retired ............ 16,042 361,196
Other ............................. 2 (204) (10) (318) (93) (2,066)
----------- ----------- ----------- ----------- ----------- -----------
Balance, end of year .............. (3,625) (93,296) (103) (2,384) (93) (2,066)
=========== ----------- =========== ----------- =========== -----------
UNEARNED ESOP STOCK
Balance, beginning of year ........ (11,674) (217,780) (12,389) (229,827) (13,371) (251,350)
Issuances related to benefit
plans ........................... 995 18,554 715 12,047 982 21,523
----------- ----------- ----------- ----------- ----------- -----------
Balance, end of year .............. (10,679) (199,226) (11,674) (217,780) (12,389) (229,827)
=========== ----------- =========== ----------- =========== -----------
RETAINED EARNINGS
Balance, beginning of year......... 1,445,081 2,013,055 1,997,490
Net income......................... 1,482,081 (141,482) 420,948
Common stock dividends - $1.50 per
share............................ (426,981) (426,492) (405,383)
----------- ----------- -----------
Balance, end of year............... 2,500,181 1,445,081 2,013,055
----------- ----------- -----------
ACCUMULATED OTHER COMPREHENSIVE LOSS
Balance, beginning of year......... (49,615) (6,455) (4,100)
Foreign currency translation
adjustments...................... (42,979) (32,790) (458)
Unrealized loss on available for
sale securities.................. (1,224) (10,370) (1,897)
----------- ----------- -----------
Balance, end of year............... (93,818) (49,615) (6,455)
----------- ----------- -----------
Total Stockholders' Equity......... $ 5,306,332 $ 4,321,868 $ 4,896,545
=========== =========== ===========
See Notes to the Consolidated Financial Statements.
62
65
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
FOR THE THREE YEARS ENDED DECEMBER 31, 1999
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) Nature of Operations.
Reliant Energy, Incorporated (Reliant Energy), formerly Houston Industries
Incorporated, together with its subsidiaries (collectively, the Company), is a
diversified international energy services company. Reliant Energy is both an
electric utility company and a utility holding company.
The Company's financial reporting segments include the following: Electric
Operations, Natural Gas Distribution, Interstate Pipelines, Wholesale Energy,
Reliant Energy Europe, Reliant Energy Latin America and Corporate. Electric
Operations includes the operations of Reliant Energy HL&P, an electric utility.
Natural Gas Distribution consists of natural gas sales to, and natural gas
transportation for, residential, commercial and industrial customers. Interstate
Pipelines includes the 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,
marketing and risk management services, and the natural gas gathering business
in North America. Reliant Energy Europe, which was formed in 1999, is engaged in
the operation of power generation facilities in the Netherlands and plans to
participate in wholesale energy trading and marketing in Europe. Reliant Energy
Latin America primarily participates in the privatization of foreign generation
and distribution facilities and independent power projects in Latin America.
Corporate includes the Company's unregulated retail electric and gas services
businesses, a communications business, certain real estate holdings and
corporate costs.
In February 1999, the Company began doing business as Reliant Energy,
Incorporated. On May 5, 1999, the Company's shareholders approved an amendment
to its Restated Articles of Incorporation to change its name to "Reliant Energy,
Incorporated."
(b) Business Acquisitions.
For information regarding the Company's accounting for the acquisition of
capital stock of N.V. UNA (UNA) in 1999 and the acquisition of Reliant Energy
Resources Corp. (Resources Corp.) and its subsidiaries (collectively,
Resources), formerly NorAm Energy Corp., by the Company in 1997, see Note 2.
(c) Texas Electric Choice Plan and Discontinuance of SFAS No. 71 for Electric
Generation Operations.
For information regarding the Texas Electric Choice Plan (Legislation) and
discontinuance of SFAS No. 71, "Accounting for the Effects of Certain Types of
Regulation" (SFAS No. 71), for Reliant Energy HL&P's electric generation
operations, see Note 3.
(d) Regulatory Assets.
The Company applies the accounting policies established in SFAS No. 71 to
the accounts of transmission and distribution operations of Reliant Energy HL&P
and Natural Gas Distribution and to certain of the accounts of Interstate
Pipelines. For information regarding Reliant Energy HL&P's electric generation
operations' discontinuance of the application of SFAS No. 71 and the effect on
its regulatory assets, see Note 3.
The following is a list of regulatory assets/liabilities reflected on the
Company's Consolidated Balance Sheet as of December 31, 1999, detailed by
Electric Operations and other segments.
63
66
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
ELECTRIC TOTAL
OPERATIONS OTHER COMPANY
---------- ----- -------
(MILLIONS OF DOLLARS)
Recoverable impaired plant costs-- net ................................ $ 587 $ $ 587
Recoverable electric generation related regulatory assets-- net........ 952 952
Regulatory tax liability-- net ........................................ (45) (45)
Unamortized loss on reacquired debt ................................... 69 69
Other deferred debits/credits.......................................... (18) 4 (14)
---------- ----- -------
Total........................................................ $ 1,545 $ 4 $ 1,549
---------- ----- -------
Included in the above table is $191 million of regulatory liabilities
recorded as other deferred credits in the Company's Consolidated Balance Sheet
as of December 31, 1999, which primarily relates to the over recovery of
Electric Operations' fuel costs, gains on nuclear decommissioning trust funds,
regulatory tax liabilities and excess deferred income taxes.
Under a "deferred accounting" plan authorized by the Public Utility
Commission of Texas (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 Electric Generating Station (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. These costs are included in
recoverable electric generation related regulatory assets.
In 1991, Electric Operations ceased all cost deferrals related to the South
Texas Project and began amortizing such amounts on a straight-line basis. Prior
to January 1, 1999, the accumulated deferrals for "deferred accounting" were
being amortized over the estimated depreciable life of the South Texas Project.
Starting in 1991, the accumulated deferrals for the "qualified phase-in plan"
were amortized over a ten-year phase-in period. The amortization of all deferred
plant costs (which totaled $26 million for each of the years 1998 and 1997) is
included on the Company's Statements of Consolidated Income as depreciation and
amortization expense. Pursuant to the Legislation (see Note 3), the Company
discontinued amortizing deferred plant costs effective January 1, 1999.
In 1999, 1998 and 1997, the Company, as permitted by the 1995 rate case
settlement (Rate Case Settlement), also amortized $22 million, $4 million and
$66 million (pre-tax), respectively, of its investment in certain lignite
reserves associated with a canceled generating station. The remaining investment
in these reserves of $14 million is included in the above table as a component
of recoverable electric generation related regulatory assets and will be
amortized fully by December 31, 2001.
For additional information regarding recoverable impaired plant costs and
recoverable electric generation related assets, see Note 3.
If, as a result of changes in regulation or competition, the Company's
ability to recover these assets and liabilities would not be assured, then
pursuant to SFAS No. 101, "Regulated Enterprises 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 Assets to
be Disposed Of" (SFAS No. 121), the Company 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 would be required
to determine any impairment to the carrying costs of plant and inventory assets.
64
67
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(e) Principles of Consolidation.
The consolidated financial statements include the accounts of Reliant
Energy and its wholly owned and majority owned subsidiaries including, effective
as of their acquisition dates, the accounts of UNA and Resources. All
significant intercompany transactions and balances are eliminated in
consolidation.
Investments in entities in which the Company has an ownership interest
between 20% and 50% or is able to exercise significant influence are accounted
for using the equity method. For additional information regarding investments
recorded using the equity method of accounting, see Note 7.
(f) Property, Plant and Equipment and Goodwill.
Property, plant and equipment includes the following:
DECEMBER 31,
----------------------------
1999 1998
------------ ------------
(THOUSANDS OF DOLLARS)
PROPERTY, PLANT AND EQUIPMENT:
Electric ............................................ $ 16,725,004 $ 13,941,275
Natural gas ......................................... 1,941,668 1,686,159
Interstate pipelines ................................ 1,330,969 1,302,829
Other property ...................................... 136,079 72,299
------------ ------------
Total ............................................. 20,133,720 17,002,562
Less accumulated depreciation and amortization ...... 6,866,325 5,499,448
------------ ------------
Property, plant and equipment - net ............... $ 13,267,395 $ 11,503,114
============ ============
Property, plant and equipment are stated at original cost. See Note 3 for
discussion of the impairment of previously regulated electric generation plant
and equipment. Repair and maintenance costs are expensed. The cost of utility
plant and equipment retirements is charged to accumulated depreciation.
Goodwill is being amortized on a straight-line basis over 15 to 40 years.
The Company had $139 million and $77 million accumulated goodwill and other
intangibles amortization at December 31, 1999 and 1998, respectively. The
Company will periodically compare the carrying value of its goodwill to the
anticipated undiscounted future net cash flows from the businesses whose
acquisition gave rise to the goodwill and as of yet no impairment is indicated.
(g) Depreciation and Amortization Expense.
Depreciation is computed using the straight-line method based on economic
lives or a regulatory mandated method. The range of plant and equipment
depreciable lives for electric, natural gas, interstate pipelines and other
property are 2 to 58 years, 5 to 50 years, 5 to 75 years and 3 to 40 years,
respectively. Depreciation expense for 1999 was $552 million compared to $561
million for 1998 and $488 million for 1997. Goodwill amortization relating to
acquisitions including UNA and Resources was $62 million, $55 million and $22
million in 1999, 1998 and 1997, respectively. For additional information
regarding goodwill in connection with the respective acquisitions of UNA and
Resources, see Note 2. Other amortization expense, including amortization of
regulatory assets, was $297 million, $254 million and $155 million in 1999, 1998
and 1997, respectively. For information regarding amortization of deferred plant
costs and investments in certain lignite reserves included in regulatory assets
in the Consolidated Balance Sheets, see Note 1(d). For information regarding the
amortization of recoverable impaired plant costs included in regulatory assets
in the Consolidated Balance Sheets, see Note 3.
In June 1998, the Texas Utility Commission issued an order approving a
transition to competition plan (Transition Plan) filed by Electric Operations in
December 1997. In order to reduce Electric Operations' exposure to potentially
stranded costs related to generation
65
68
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
assets, the Transition Plan permitted 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 stated 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 $104 million
in additional depreciation and $99 million in redirected depreciation for the
first six months in 1999 and $194 million in additional depreciation and $195
million in redirected depreciation in 1998 pursuant to the Transition Plan. Due
to the discontinuance of SFAS No. 71 to Electric Operations' generation
operations, the provisions for additional and redirected depreciation of the
Transition Plan are no longer applied. For additional information regarding
this legislation, see Note 3.
Pursuant to the Legislation, the Company is allowed to recover the
generation related regulatory assets reported in the Company's Form 10-K as of
December 31, 1998. Therefore, the Company discontinued amortizing certain
generation related regulatory assets effective as of January 1, 1999.
The Company's depreciation expense included $50 million of additional
depreciation relating to the South Texas Project in 1997. The depreciation
expense recorded for the South Texas Project was made pursuant to the terms of
the Company's 1995 Rate Case Settlement.
(h) Fuel Stock and Petroleum Products.
Gas inventory (primarily using the average cost method) was $93 million and
$96 million at December 31, 1999 and 1998, respectively. Coal and lignite
inventory balances (using last-in, first-out) were $46 million and $31 million
at December 31, 1999 and 1998, respectively. Oil inventory balances, principally
heating oil, were $13 million and $85 million at December 31, 1999 and 1998,
respectively. Heating oil that is used in trading operations is marked-to-market
in connection with the price risk management activities as discussed in Note 5.
(i) Revenues.
The Company records electricity and natural gas sales under the accrual
method, whereby unbilled electricity and natural gas sales are estimated and
recorded each month. Reliant Energy Latin America revenues include electricity
sales of majority owned foreign electric utilities, which are also recorded
under the accrual method, and equity income (net of foreign taxes) in equity
investments. In 1998, Reliant Energy Latin America's revenues included the gain
on the sale of an Argentine distribution system. In 1998, the Company adopted
mark-to-market accounting for its energy price risk management and trading
activities. (See Notes 1(o) and 5).
(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 to cash.
(k) Income Taxes.
The Company files a consolidated federal income tax return. The Company
follows a policy of comprehensive interperiod income tax allocation. The Company
uses the liability method of accounting for deferred income taxes and measures
deferred income taxes for all significant income tax temporary differences.
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 13.
(l) Investment in Other Debt and Equity Securities.
The debt and equity 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 $145 million
as of December 31, 1999
66
69
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
and $119 million as of December 31, 1998 in the Company's Consolidated Balance
Sheets in deferred debits. The liability for nuclear decommissioning is reported
in the Company's Consolidated Balance Sheets in other deferred credits. Any
unrealized losses or gains are accounted for in accordance with SFAS No. 71 as a
regulatory asset/liability.
The Company also holds certain other marketable equity securities
classified as "available-for-sale" and reports such investments at estimated
fair value in 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, 1999 and
1998, the accumulated unrealized loss, net of tax, relating to these equity
securities was $17 million and $16 million, respectively.
UNA holds $133 million of debt securities which are classified as "trading"
in accordance with SFAS No. 115. As of December 31, 1999, this investment is
recorded in deferred debits in the Company's Consolidated Balance Sheet. For
information regarding the Company's investment in Time Warner common stock which
is classified as "trading" under SFAS No. 115, see Note 8.
(m) Foreign Currency Adjustments.
Foreign subsidiaries' 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 in other comprehensive
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 Brazil and the devaluation of the Brazilian real in 1999, see Note 7.
When the U.S. dollar is the functional currency, the financial statements
of such foreign subsidiaries 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.
(n) Reclassifications and Use of Estimates.
Certain amounts from the previous years have been reclassified to conform
to the 1999 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,
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.
(o) Change in Accounting Principle.
For discussion of discontinuance of SFAS No. 71 to the Reliant Energy
HL&P's electric generation operations, see Note 3.
In the fourth quarter of 1998, the Company adopted mark-to-market
accounting for all of its energy price risk management and trading activities.
Under mark-to-market accounting, the Company records the fair value of energy
related derivative financial instruments, including physical forward contracts,
swaps, options and exchange-traded futures and option contracts at each balance
sheet date. Such amounts are recorded as price risk management assets and
liabilities in the Company's Consolidated Balance Sheets. The realized and
unrealized gains and losses are
67
70
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
recorded as a component of revenues. The Company applied mark-to-market
accounting retroactively to January 1, 1998. There was no material cumulative
effect resulting from this accounting change.
The Company adopted Emerging Issues Task Force Issue 98-10, "Accounting for
Contracts Involved in Energy Trading and Risk Management Activities" (EITF
98-10) in 1999. The adoption of EITF 98-10 had no material impact on the
consolidated financial statements.
(p) New Accounting Pronouncement.
Effective January 1, 2001, the Company is required to adopt SFAS No. 133,
"Accounting for Derivative Instruments and Hedging Activities" as amended (SFAS
No. 133), which establishes accounting and reporting standards for derivative
instruments, including certain hedging instruments embedded in other contracts
and for hedging activities. The Company is in the process of determining the
effect of adopting SFAS No. 133 on its consolidated financial statements.
(2) BUSINESS ACQUISITIONS
During 1999, the Company completed the first two phases of the acquisition
of UNA, a Dutch power generation company. The Company acquired 40% and 12% of
UNA's capital stock on October 7, 1999 and December 1, 1999, respectively. The
aggregate purchase price paid by the Company in connection with the first two
phases consisted of a total of $833 million in cash and $426 million in a
five-year promissory note to UNA. Under the terms of the acquisition agreement,
the Company purchased the remaining shares of UNA on March 1, 2000 for
approximately $975 million. The commitment for this purchase was recorded as a
business purchase obligation in the Consolidated Balance Sheet as of December
31, 1999 based on an exchange rate of 2.19 Dutch guilders (NLG) per U.S. dollar
(the exchange rate on December 31, 1999). A portion ($596 million) of the
business purchase obligation was recorded as a non-current liability as this
portion of the obligation was financed with a three-year term loan facility (see
Note 19). Effective October 1, 1999, the Company has recorded 100% of the
operating results of UNA. The total purchase price, payable in NLG, of
approximately $2.4 billion includes the $426 million promissory note to UNA and
assumes an exchange rate of 2.0565 NLG per U.S. dollar (the exchange rate on
October 7, 1999). The Company recorded the acquisition under the purchase method
of accounting with assets and liabilities of UNA reflected at their estimated
fair values. The excess of the purchase price over the fair value of net assets
acquired of approximately $840 million was recorded as goodwill and is being
amortized over 35 years. On a preliminary basis, the Company's fair value
adjustments included increases in property, plant and equipment, long-term debt,
and related deferred taxes. The Company expects to finalize these fair value
adjustments during 2000; however, it is not anticipated that any additional
adjustments will be material.
In August 1997 , the former parent corporation (Former Parent) of the
Company, merged with and into Reliant Energy, and NorAm Energy Corp., a natural
gas gathering, transmission, marketing and distribution company (Former NorAm),
merged with and into Resources Corp. 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. The Company recorded the
acquisition under the purchase method of accounting with assets and liabilities
of Former NorAm reflected at their estimated fair values. The Company recorded
the excess of the acquisition cost over the fair value of the net assets
acquired of $2.1 billion 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.
68
71
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The Company's results of operations incorporate UNA's and Resources'
results of operations only for the period beginning with the effective date of
their respective acquisition. The following tables present certain actual
financial information for the years ended December 31, 1999, 1998 and 1997;
unaudited pro forma information for the years ended December 31, 1999 and 1998,
as if the acquisition of UNA had occurred on January 1, 1999 and 1998; and
unaudited pro forma information for the year ended December 31, 1997, as if the
Merger with Resources had occurred on January 1, 1997.
ACTUAL AND PRO FORMA COMBINED RESULTS OF OPERATIONS
(IN MILLIONS, EXCEPT PER SHARE DATA)
YEAR ENDED DECEMBER 31,
------------------------------------------------------------------------
1999 1998 1997
--------------------- ---------------------- ----------------------
ACTUAL PRO FORMA ACTUAL PRO FORMA ACTUAL PRO FORMA
-------- --------- -------- --------- -------- ---------
(UNAUDITED) (UNAUDITED) (UNAUDITED)
Revenues................................. $ 15,303 $15,784 $ 11,488 $ 12,320 $ 6,878 $ 10,191
Net income (loss) attributable to
common stockholders................... 1,482 1,525 (141) (61) 421 437
Basic earnings per share................. 5.20 5.35 (.50) (.21) 1.66 1.55
Diluted earnings per share............... 5.18 5.33 (.50) (.21) 1.66 1.55
These pro forma results 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 if
the acquisition of UNA had occurred on January 1, 1999 and 1998 and the Merger
with Resources had occurred on January 1, 1997. 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 UNA and Resources assets and liabilities.
(3) TEXAS ELECTRIC CHOICE PLAN AND DISCONTINUANCE OF SFAS NO. 71 FOR ELECTRIC
GENERATION OPERATIONS
In June 1999, the Texas legislature adopted the Texas Electric Choice Plan
(Legislation). The Legislation substantially amends the regulatory structure
governing electric utilities in Texas in order to allow retail competition
beginning with respect to pilot projects for up to 5% of each utility's load in
all customer classes in June 2001 and for all other customers on January 1,
2002. In preparation for that competition, the Company expects to make
significant changes in the electric utility operations it conducts through
Reliant Energy HL&P. In addition, the Legislation requires the Texas Utility
Commission to issue a number of new rules and determinations in implementing the
Legislation.
The Legislation defines the process for competition and creates a
transition period during which most utility rates are frozen at rates not in
excess of their present levels. The Legislation provides for utilities to
recover their generation related stranded costs and regulatory assets (as
defined in the Legislation).
Retail Choice. Under the Legislation, on January 1, 2002, most retail
customers of investor-owned electric utilities in Texas will be entitled to
purchase their electricity from any of a number of "retail electric providers"
which will have been certified by the Texas Utility Commission. Retail electric
providers will not own or operate generation assets and their sales rates will
not be subject to traditional cost-of-service rate regulation. Retail electric
providers which are affiliates of electric utilities may compete substantially
statewide for these sales, but rates they charge within the affiliated electric
utility's traditional service territory are subject to certain limitations at
the outset of retail choice, as described below. The Texas Utility Commission
will prescribe regulations governing quality, reliability and other aspects of
service from retail electric providers. Transmission between the regulated
utility and its current and future competitive affiliates is subject to
regulatory scrutiny and must comply with a code of conduct established by the
Texas Utility Commission. The code of conduct governs interactions between
employees of regulated and current and future unregulated affiliates as well as
the exchange of information between such affiliates.
69
72
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Unbundling. By January 1, 2002, electric utilities in Texas such as Reliant
Energy HL&P will restructure their businesses in order to separate power
generation, transmission and distribution, and retail activities into different
units. Pursuant to the Legislation, the Company submitted a plan in January 2000
to accomplish the required separation of its regulated operations into separate
units and is awaiting approval from the Texas Utility Commission. The
transmission and distribution business will continue to be subject to
cost-of-service rate regulation and will be responsible for the delivery of
electricity to retail consumers.
Generation. Power generators will sell electric energy to wholesale
purchasers, including retail electric providers, at unregulated rates beginning
January 1, 2002. To facilitate a competitive market, Reliant Energy HL&P and
most other electric utilities will be required to sell at auction entitlements
to 15% of their installed generating capacity no later than 60 days before
January 1, 2002. That obligation to auction entitlements continues until the
earlier of January 1, 2007 or the date the Texas Utility Commission determines
that at least 40% of the residential and small commercial load served in the
electric utility's service area is being served by non-affiliated retail
electric providers. In addition, a power generator that owns and controls more
than 20% of the power generation in, or capable of delivering power to, a power
region after the reductions from the capacity auction (calculated as prescribed
in the Legislation) must submit a mitigation plan to reduce generation that it
owns and controls to no more than 20% in the power region. The Legislation also
creates a program mandating air emissions reductions for non-permitted
generating facilities. The Company anticipates that any stranded costs
associated with this obligation incurred before May 1, 2003 will be recoverable
through the stranded cost recovery mechanisms contained in the Legislation.
Rates. Base rates charged by Reliant Energy HL&P on September 1, 1999 will
be frozen until January 1, 2002. Effective January 1, 2002, retail rates charged
to residential and small commercial customers by the utility's affiliated retail
electric provider will be reduced by 6% from the average rates (on a bundled
basis) in effect on January 1, 1999. That reduced rate will be known as the
"price to beat" and will be charged by the affiliated retail electric provider
to residential and small commercial customers in Reliant Energy HL&P's service
area who have not elected service from another retail electric provider. The
affiliated retail electric provider may not offer different rates to residential
or small commercial customer classes in the utility's service area until the
earlier of the date the Texas Utility Commission determines that 40% of power
consumed by that class is being served by non-affiliated retail electric
providers or January 1, 2005. In addition, the affiliated retail electric
provider must make the price to beat available to eligible consumers until
January 1, 2007.
Stranded Costs. Reliant Energy HL&P will be entitled to recover its
stranded costs (i.e., the excess of net book value of generation assets (as
defined by the Legislation) over the market value of those assets) and its
regulatory assets related to generation. The Legislation prescribes specific
methods for determining the amount of stranded costs and the details for their
recovery. However, during the base rate freeze period from 1999 through 2001,
earnings above the utility's authorized return formula will be applied in a
manner to accelerate depreciation of generation related plant assets for
regulatory purposes. In addition, depreciation expense for transmission and
distribution related assets may be redirected to generation assets for
regulatory purposes during that period.
The Legislation provides for Reliant Energy HL&P, or a special purpose
entity, to issue securitization bonds for the recovery of generation related
regulatory assets and stranded costs. These bonds will be sold to third parties
and will be amortized through non-bypassable charges to transmission and
distribution customers. Any stranded costs not recovered through the
securitization bonds will be recovered through a non-bypassable charge to
transmission and distribution customers. Costs associated with nuclear
decommissioning that have not been recovered as of January 1, 2002, will
continue to be subject to cost-of-service rate regulation and will be included
in a non-bypassable charge to transmission and distribution customers.
In November 1999, Reliant Energy HL&P filed an application with the Texas
Utility Commission requesting a financing order authorizing the issuance by a
special purpose entity organized by the Company, pursuant to the Legislation, of
transition bonds related to Reliant Energy HL&P's generation-related regulatory
assets. The Company believes the Texas Utility Commission will authorize the
issuance of approximately $750 million of
70
73
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
transition bonds. Payments on the transition bonds will be made out of funds
derived from non-bypassable transition charges to Reliant Energy HL&P's
transmission and distribution customers. The offering and sale of the transition
bonds will be registered under the Securities Act of 1933 and, absent any
appeals, are expected to be consummated in the second or third quarter of 2000.
Accounting. Historically, Reliant Energy HL&P has applied the accounting
policies established in SFAS No. 71. 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 it meets the following requirements: (1) its rates are regulated
by a third party; (2) its rates are cost-based; and (3) there exists a
reasonable assumption that all costs will be recoverable from customers through
rates. When a company determines that it no longer meets the requirements of
SFAS No. 71, pursuant to SFAS No. 101 and SFAS No. 121, it is required to write
off regulatory assets and liabilities unless some form of recovery continues
through rates established and collected from remaining regulated operations. In
addition, such company is required to determine any impairment to the carrying
costs of deregulated plant and inventory assets in accordance with SFAS No. 121.
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 No. 97-4). EITF No. 97-4 concluded
that a company should stop applying SFAS No. 71 to a segment which is subject to
a deregulation plan at the time the deregulation legislation or enabling rate
order contains sufficient detail for the utility to reasonably determine how the
plan will affect the segment to be deregulated. In addition, EITF No. 97-4
requires that regulatory assets and liabilities be allocated to the applicable
portion of the electric utility from which the source of the regulated cash
flows will be derived.
The Company believes that the Legislation provides sufficient detail
regarding the deregulation of the Company's electric generation operations to
require it to discontinue the use of SFAS No. 71 for those operations. Effective
June 30, 1999, the Company applied SFAS No. 101 to its electric generation
operations. Reliant Energy HL&P's transmission and distribution operations
continue to meet the criteria of SFAS No. 71.
In 1999, the Company evaluated the recovery of its generation related
regulatory assets and liabilities. The Company determined that a pre-tax
accounting loss of $282 million exists because it believes only the economic
value of its generation related regulatory assets (as defined by the
Legislation) will be recovered. Therefore, the Company recorded a $183 million
after tax extraordinary loss in the fourth quarter of 1999. If events were to
occur that made the recovery of certain of the remaining generation related
regulatory assets no longer probable, the Company would write off the remaining
balance of such assets as a non-cash charge against earnings. Pursuant to EITF
No. 97-4, the remaining recoverable regulatory assets will not be written off
and will become associated with the transmission and distribution portion of the
Company's electric utility business. For details regarding the Reliant Energy
HL&P's regulatory assets, see Note 1(d).
At June 30, 1999, the Company performed an impairment test of its
previously regulated electric generation assets pursuant to SFAS No. 121 on a
plant specific basis. Under SFAS No. 121, an asset is considered impaired, and
should be written down to fair value, if the future undiscounted net cash flows
expected to be generated by the use of the asset are insufficient to recover the
carrying amount of the asset. For assets that are impaired pursuant to SFAS No.
121, the Company determined the fair value for each generating plant by
estimating the net present value of future cash inflows and outflows over the
estimated life of each plant. The difference between fair value and net book
value was recorded as a reduction in the current book value. The Company
determined that $797 million of electric generation assets were impaired as of
June 30, 1999. Of such amounts, $745 million relates to the South Texas Project
and $52 million relates to two gas-fired generation plants. The Legislation
provides recovery of this impairment through regulated cash flows during the
transition period and through non-bypassable charges to transmission and
distribution customers. As such, a regulatory asset has been recorded for an
amount equal to the
71
74
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
impairment loss and is included on the Company's Consolidated Balance Sheets as
a regulatory asset. In addition, the Company recorded an additional $12 million
of recoverable impaired plant costs in the third quarter of 1999 related to
previously incurred costs that are now estimated to be recoverable pursuant to
the Legislation. During the third and fourth quarter of 1999, the Company
recorded amortization expense related to the recoverable impaired plant costs
and other deferred debits created from discontinuing SFAS No. 71 of $221
million. The Company will continue to amortize this regulatory asset as it is
recovered from regulated cash flows.
The impairment analysis requires estimates of possible future market
prices, load growth, competition and many other factors over the lives of the
plants. The resulting impairment loss is highly dependent on these underlying
assumptions. In addition, after January 10, 2004, Reliant Energy HL&P must
finalize and reconcile stranded costs (as defined by the Legislation) in a
filing with the Texas Utility Commission. Any difference between the fair market
value and the regulatory net book value of the generation assets (as defined by
the Legislation) will either be refunded or collected through future
non-bypassable charges. This final reconciliation allows alternative methods of
third party valuation of the fair market value of these assets, including
outright sale, stock valuations and asset exchanges. Because generally accepted
accounting principles require the Company to estimate fair market values on a
plant-by-plant basis in advance of the final reconciliation, the financial
impacts of the Legislation with respect to stranded costs are subject to
material changes. Factors affecting such change may include estimation risk,
uncertainty of future energy prices and the economic lives of the plants. If
events occur that make the recovery of all or a portion of the regulatory assets
associated with the generation plant impairment loss and deferred debits created
from discontinuance of SFAS No. 71 pursuant to the Legislation no longer
probable, the Company will write off the corresponding balance of such assets as
a non-cash charge against earnings. One of the results of discontinuing the
application of SFAS No. 71 for the generation operations is the elimination of
the regulatory accounting effects of excess deferred income taxes and investment
tax credits related to such operations. The Company believes it is probable that
some parties will seek to return such amounts to ratepayers and accordingly, the
Company has recorded an offsetting liability.
Following are the classes of electric property, plant and equipment at
cost, with associated accumulated depreciation at December 31, 1999 (including
the impairment loss discussed above) and December 31, 1998.
TRANSMISSION CONSOLIDATED
AND GENERAL ELECTRIC PLANT IN
GENERATION DISTRIBUTION AND INTANGIBLE SERVICE
------------ ------------ -------------- -----------------
(MILLIONS OF DOLLARS)
December 31, 1999:
Original cost............................ $ 11,202 $ 4,531 $ 992 $ 16,725
Accumulated depreciation................. 4,767 1,263 251 6,281
----------- ----------- ----------- --------------
Property, plant and equipment - net(1)... $ 6,435 $ 3,268 $ 741 $ 10,444
=========== =========== =========== ==============
December 31, 1998:
Original cost............................ $ 8,843 $ 4,196 $ 902 $ 13,941
Accumulated depreciation................. 3,822 1,276 207 5,305
----------- ----------- ----------- --------------
Property, plant and equipment - net(1)... $ 5,021 $ 2,920 $ 695 $ 8,636
=========== =========== =========== ==============
- ----------
(1) Includes non-rate regulated domestic and international generation
facilities of $696 million and $338 million at December 31, 1999 and 1998,
respectively, and international distribution facilities of $32 million and
$19 million at December 31, 1999 and 1998, respectively. Also, includes
property, plant and equipment of UNA of $1.8 billion at December 31, 1999.
In order to reduce potential exposure to stranded costs related to
generation assets, Reliant Energy HL&P redirected $99 million and $195 million
of depreciation in the six months ended June 30, 1999, and the year ended
December 31, 1998, respectively, from transmission and distribution related
plant assets to generation assets for regulatory and financial reporting
purposes. Such redirection was in accordance with the Company's Transition
72
75
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Plan. See Note 4 for additional information regarding the Transition Plan. The
Legislation provides that depreciation expense for transmission and distribution
related assets may be redirected to generation assets during the base rate
freeze period from 1999 through 2001. For regulatory purposes, the Company has
continued to redirect transmission and distribution depreciation to generation
assets. Beginning June 30, 1999, redirected depreciation expense cannot be
recorded by the electric generation operations portion of Reliant Energy HL&P
for financial reporting purposes as this portion of electric operations is no
longer accounted for under SFAS No. 71. During the third and fourth quarters of
1999, $99 million in depreciation expense has been redirected from transmission
and distribution for regulatory purposes and has been established as an embedded
regulatory asset included in transmission and distribution related plant and
equipment balances. As of December 31, 1999 and 1998, the cumulative amount of
redirected depreciation for regulatory purposes is $393 million and $195
million, respectively.
The Company reviewed its long-term purchase power contracts and fuel
contracts for potential loss in accordance with SFAS No. 5, "Accounting for
Contingencies" and Accounting Research Bulletin No. 43, Chapter 4, "Inventory
Pricing." Based on projections of future market prices for wholesale
electricity, the analysis indicated no loss recognition is appropriate at this
time.
Other Accounting Policy Changes. As a result of discontinuing SFAS No. 71,
the accounting policies discussed below related to Electric Operations'
generation operations have been changed effective July 1, 1999. Allowance for
funds used during construction will no longer be accrued on generation related
construction projects. Instead, interest will be capitalized on these projects
in accordance with SFAS No. 34, "Capitalization of Interest Cost."
Previously, in accordance with SFAS No. 71, Reliant Energy HL&P deferred
the premiums and expenses that arose when long term debt was redeemed and
amortized these costs over the life of the new debt. If no new debt was issued,
these costs were amortized over the remaining original life of the retired debt.
Effective July 1, 1999, costs resulting from the retirement of debt attributable
to the generation operations of Reliant Energy HL&P will be recorded in
accordance with SFAS No. 4, "Reporting Gains and Losses from Extinguishment of
Debt," unless such costs will be recovered through regulated cash flows. In that
case, these costs will be deferred and recorded as a regulatory asset by the
entity through which the source of the regulated cash flows will be derived.
During the third and fourth quarters of 1999, the generation portion of Reliant
Energy HL&P incurred $11 million of losses from extinguishment of debt which
Reliant Energy HL&P's transmission and distribution operations have recorded as
a regulatory asset. This regulatory asset will be amortized along with
recoverable impaired plant costs as the assets are recovered pursuant to the
Legislation.
(4) 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 additional information regarding the Transition
Plan, see Note 1(g).
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. The Office of the Attorney General has withdrawn its
appeal, but the Texas municipality continues to maintain its appeal. Because of
the number of variables that can affect the ultimate resolution of an appeal of
Texas Utility Commission orders, the Company cannot predict the outcome of this
matter or the ultimate effect that adverse action by the courts could have on
the Company.
73
76
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(5) DERIVATIVE FINANCIAL INSTRUMENTS
(a) Price Risk Management and Trading Activities.
The Company offers energy price risk management services primarily related
to natural gas, electricity, crude oil and refined products, weather, coal and
certain air emissions regulatory credits. The Company provides these services by
utilizing a variety of derivative financial instruments, including fixed and
variable-priced physical forward contracts, fixed and variable-priced swap
agreements and options traded in the over-the-counter financial markets and
exchange-traded energy futures and option contracts (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, the Company applied hedge accounting to certain physical
commodity activities that qualified for hedge accounting. In 1998, the Company
adopted mark-to-market accounting for all of its price risk management and
trading activities. Accordingly, since 1998, such Trading Derivatives are
recorded at fair value with realized and unrealized gains (losses) recorded as a
component of revenues. The recognized, unrealized balance is included in price
risk management assets/liabilities (See Note 1(o)).
The notional quantities, maximum terms and the estimated fair value of
Trading Derivatives at December 31, 1999 and 1998 are presented below (volumes
in billions of British thermal units equivalent (Bbtue) and dollars in
millions):
VOLUME-FIXED
VOLUME-FIXED PRICE MAXIMUM
PRICE PAYOR RECEIVER TERM (YEARS)
------------ ------------ ------------
1999
Natural gas................................................. 936,716 939,416 9
Electricity................................................. 251,592 248,176 10
Crude oil and refined products.............................. 143,857 144,554 3
1998
Natural gas................................................. 937,264 977,293 9
Electricity................................................. 122,950 124,878 3
Crude oil and refined products.............................. 205,499 204,223 3
FAIR VALUE AVERAGE FAIR VALUE (a)
------------------------ ------------------------
ASSETS LIABILITIES ASSETS LIABILITIES
--------- ----------- --------- -----------
1999
Natural gas............................................. $ 319 $ 299 $ 302 $ 283
Electricity............................................. 131 98 103 80
Crude oil and refined products.......................... 134 145 127 132
--------- --------- --------- ---------
$ 584 $ 542 $ 532 $ 495
========= ========= ========= =========
1998
Natural gas............................................. $ 224 $ 212 $ 124 $ 108
Electricity............................................. 34 33 186 186
Crude oil and refined products.......................... 29 23 21 17
--------- --------- --------- ---------
$ 287 $ 268 $ 331 $ 311
========= ========= ========= =========
- ----------
(a) Computed using the ending balance of each quarter.
74
77
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In addition to the fixed-price notional volumes above, the Company also has
variable-priced agreements, as discussed above, totaling 3,797,824 and 1,702,977
Bbtue as of December 31, 1999 and 1998, 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 values shown in the tables above at December 31, 1999 and
1998 have been recognized in income. The fair value as of December 31, 1999 and
1998 was estimated using quoted prices where available and considering the
liquidity of the market for the Trading Derivatives. The prices and fair values
are subject to significant changes based on changing market conditions.
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's 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 the Company as of December 31, 1999 and 1998.
DECEMBER 31, 1999 DECEMBER 31, 1998
------------------------ ---------------------------
INVESTMENT INVESTMENT
GRADE (1) TOTAL GRADE (1) TOTAL
----------- ---------- ----------- ------------
(MILLIONS OF DOLLARS)
Energy marketers.................................. $ 172 $ 183 $ 103 $ 124
Financial institutions............................ 119 119 62 62
Gas and electric utilities........................ 184 186 47 48
Oil and gas producers............................. 6 30 7 8
Industrials....................................... 4 5 2 3
Independent power producers....................... 4 6 1 1
Others............................................ 64 67 45 47
----------- ---------- ----------- -----------
Total........................................ $ 553 596 $ 267 293
=========== ===========
Credit and other reserves......................... (12) (6)
---------- -----------
Energy price risk management assets (2)........... $ 584 $ 287
========== ===========
- ---------
(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) As of December 31, 1999, the Company had no credit risk exposure to any
single counterparty that represents greater than 5% of price risk
management assets.
(b) Non-Trading Activities.
To reduce the risk from market fluctuations in the revenues derived from
electric power, natural gas and related transportation, the Company enters 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
and to protect natural
75
78
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
gas distribution earnings against unseasonably warm weather during peak gas
heating months, although usage to date for this purpose has not been material.
The Company applies hedge accounting with respect to its derivative financial
instruments utilized in non-trading activities.
The Company utilizes 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 utilizes such derivatives to effectively
fix the interest rate on debt expected to be issued for refunding purposes. In
addition, in 1999, the Company entered into foreign currency swaps to hedge a
portion of its investment in UNA.
For transactions involving either Energy Derivatives or interest-rate and
foreign currency derivatives, hedge accounting is applied only if the derivative
(i) reduces the 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.
In the case of the foreign currency swaps which hedge a portion of the
Company's investment in UNA, income or loss associated with the foreign currency
derivative transactions is recorded as foreign currency translation adjustments
as a component of stockholders' equity. Such amounts generally offset amounts
recorded in stockholders' equity as adjustments resulting from translation of
the hedged investment into U.S. dollars.
Unrealized changes in the market value of Energy Derivatives utilized as
hedges are not generally recognized in the Company's Statements of Consolidated
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, 1999, the Company was fixed-price payors and fixed-price
receivers in Energy Derivatives covering 33,108 billion British thermal units
(Bbtu) and 5,481 Bbtu of natural gas, respectively. At December 31, 1998, the
Company was fixed-price payors and fixed-price receivers in Energy Derivatives
covering 42,498 Bbtu and 3,930 Bbtu of natural gas, respectively. Also, at
December 31, 1999 and 1998, the Company was a party to variable-priced Energy
Derivatives totaling 44,958 Bbtu and 21,437 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 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.
76
79
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The average maturity discussed above and the fair value discussed in Note
15 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 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 has 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 enters into such contracts primarily
with counterparties having a minimum Standard & Poor's or Moody's rating of BBB-
or Baa3, respectively. For long-term arrangements, the Company periodically
reviews 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 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
losses 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.
The Company's policies also prohibit the use of leveraged financial
instruments.
The Company has established a Risk Oversight Committee, comprised of
corporate and business segment officers that oversees all commodity price and
credit risk activities, including the Company's trading, marketing and risk
management activities. The committee's duties are to establish the Company's
commodity risk policies, allocate risk capital within limits established by the
Company's board of directors, approve trading of new products and commodities,
monitor risk positions and ensure compliance with the Company's risk management
policies and procedures and trading limits established by the Company's board of
directors.
(6) 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, 1999, the Company's investment in the South Texas Project was $382
million (net of $2.1 billion accumulated depreciation which includes an
impairment loss recorded in 1999 of $745 million). For additional information
regarding the impairment loss, see Note 3. The Company's investment in nuclear
fuel was $44 million (net of $251 million amortization) as of such date.
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 operating responsibility for the
South Texas Project to the South Texas Project 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
77
80
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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 $17 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 was $8.9 billion as of December 31, 1999. 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 $84 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(l). In July 1999, an outside
consultant estimated the Company's portion of decommissioning costs to be
approximately $363 million. 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 and changes in regulatory requirements, technology and costs of
labor, materials and equipment. Pursuant to the Legislation, costs associated
with nuclear decommissioning that have not been recovered as of January 1, 2002,
will continue to be subject to cost-of-service rate regulation and will be
included in a non-bypassable charge to transmission and distribution customers.
(7) EQUITY INVESTMENTS AND ADVANCES TO UNCONSOLIDATED SUBSIDIARIES
The Company accounts for investments in unconsolidated subsidiaries under
the equity method of accounting where (i) the ownership interest in the
affiliate ranges from 20% to 50%, (ii) the ownership interest is less than 20%
but the Company exercises significant influence over operating and financial
policies of such affiliate or (iii) the interest in the affiliate exceeds 50%
but the Company does not exercise control over the affiliate.
78
81
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The Company's equity investments and advances in unconsolidated
subsidiaries at December 31, 1999 and 1998 were $1 billion and $1.1 billion,
respectively. The Company's equity loss from these investments, was $14 million
in 1999. For 1998 and 1997, the Company's equity income from these investments
was $71 million and $49 million, respectively. Dividends received from these
investments amounted to $14 million, $44 million and $46 million in 1999, 1998
and 1997, respectively.
(a) Reliant Energy Latin America.
Reliant Energy is evaluating the sale of the Company's Latin American
assets in order to pursue business opportunities that are in line with its
strategies for the U.S. and Western Europe.
As of December 31, 1999, Reliant Energy Latin America indirectly holds
interests in Light Servicos de Eletricidade S.A. (Light) (11.78%) which
transmits and distributes electricity in Rio De Janeiro, Brazil and holds 77.81%
of the common stock of Metropolitana Electricidade de Sao Paulo S.A.
(Metropolitana) which transmits and distributes electricity in Sao Paulo,
Brazil; three Colombian electric systems, Empresa de Energia del Pacifico
S.A.E.S.P. (EPSA) (28.35%), Electricaribe (34.61%), and Electrocosta (35.17%);
and three electric systems in El Salvador (ranging from approximately 37% to
45%). In addition, Reliant Energy Latin America indirectly holds interests in
natural gas systems in Colombia and a power generation plant in India.
As of December 31, 1999 and 1998, Light and Metropolitana had total
borrowings of $2.9 billion and $3.2 billion denominated in non-local currencies.
During the first quarter of 1999, the Brazilian real was devalued and allowed to
float against other major currencies. The effects of devaluation on the
non-local currency denominated borrowings caused the Company to record, as a
component of its equity earnings, an after-tax charge for the year ended
December 31, 1999 of $102 million as a result of foreign currency transaction
losses recorded by both Light and Metropolitana. At December 31, 1999 and 1998,
one U.S. dollar could be exchanged for 1.79 Brazilian real and 1.21 Brazilian
real, respectively. Because the Company uses the Brazilian real as the
functional currency to report Light's equity earnings, any decrease in the value
of the Brazilian real below its December 31, 1999 level will increase Light's
liability represented by the non-local currency denominated borrowings. This
amount will also be reflected in the Company's consolidated earnings, to the
extent of the Company's ownership interest in Light. Similarly, any increase in
the value of the Brazilian real above its December 31, 1999 level will decrease
Light's liability represented by such borrowings.
In April 1998, Light purchased 74.88% of the common stock of Metropolitana.
The purchase price for the shares was approximately $1.8 billion and was
financed with proceeds from bank borrowings. In August 1998, Reliant Energy
Latin America and another unrelated entity jointly acquired, through
subsidiaries, 65% of the stock of two Colombian electric distribution companies,
Electricaribe and Electrocosta, for approximately $522 million. The shares of
these companies are indirectly held by an offshore holding company jointly owned
by the Company and the other entity. In addition, in 1998, the Company acquired,
for approximately $150 million, equity interests in three electric distribution
systems located in El Salvador.
In June 1997, a consortium of investors which included Reliant Energy Latin
America acquired for $496 million a 56.7% controlling ownership interest in
EPSA. Reliant Energy Latin America contributed $152 million of the purchase
price for a 28.35% ownership interest in EPSA.
In May 1997, Reliant Energy Latin America 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 Latin
America sold its 63% ownership interest in this Argentine affiliate and certain
related assets for approximately $243 million. Reliant Energy Latin America
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.
79
82
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(b) Wholesale Energy Domestic.
In April 1998, the Company formed a limited liability corporation to
construct and operate a 490 MW electric generation plant in Boulder City, Nevada
in which the Company retained a 50% interest. The plant is anticipated to be
operational in the second quarter of 2000. In October 1998, the Company entered
into a partnership to construct and operate a 100 MW cogeneration plant in
Orange, Texas in which its ownership interest is 50%. The plant began commercial
operation in December 1999. As of December 31, 1999, the Company's net
investment in these projects is $78 million and its total projected net
investment is approximately $90 million.
(c) Combined Financial Statement Data of Equity Investees and Advances to
Unconsolidated Subsidiaries.
The following tables set forth certain summarized financial information of
the Company's unconsolidated affiliates as of December 31, 1999 and 1998 and for
the years then ended or periods from the respective affiliates' acquisition date
through December 31, 1999, 1998 and 1997, if shorter:
YEAR ENDED DECEMBER 31,
------------------------------------------
1999 1998 1997
------------ ----------- -----------
(THOUSANDS OF DOLLARS)
Income Statement:
Revenues................................................. $ 4,421,942 $ 2,449,335 $ 2,011,927
Operating expenses....................................... 3,329,559 1,762,166 1,460,248
Net income............................................... (310,667) 514,005 403,323
DECEMBER 31,
-----------------------------
1999 1998
------------ ------------
(THOUSANDS OF DOLLARS)
Balance Sheet:
Current assets........................................................ $ 1,553,166 $ 1,841,857
Noncurrent assets..................................................... 10,379,306 13,643,747
Current liabilities................................................... 2,714,621 4,074,603
Noncurrent liabilities................................................ 4,440,985 6,284,821
Owners' equity........................................................ 4,776,866 5,126,180
(8) INDEXED DEBT SECURITIES (ACES AND ZENS) AND TIME WARNER SECURITIES
(a) Original investment in Time Warner Securities.
On July 6, 1999, the Company converted its 11 million shares of Time Warner
Inc. (TW) convertible preferred stock (TW Preferred) into 45.8 million shares of
Time Warner common stock (TW Common). Prior to the conversion, the Company's
investment in the TW Preferred was accounted for under the cost method at a
value of $990 million in the Company's Consolidated Balance Sheets. The TW
Preferred was redeemable after July 6, 2000, had an aggregate liquidation
preference of $100 per share (plus accrued and unpaid dividends), was entitled
to annual dividends of $3.75 per share until July 6, 1999 and was convertible by
the Company. The Company recorded pre-tax dividend income with respect to the TW
Preferred of $20.6 million in 1999 prior to the conversion and $41.3 million in
both 1998 and 1997. Due to the conversion, the Company will no longer receive
the quarterly pre-tax dividend of $10.3 million that was paid on the TW
Preferred but will receive dividends, if declared and paid, on its investments
in TW Common. Effective on the conversion date, the shares of TW Common were
classified as trading securities under SFAS No. 115 and an unrealized gain was
recorded in the amount of $2.4 billion ($1.5 billion after tax) to reflect the
cumulative appreciation in the fair value of the Company's investment in Time
Warner securities.
80
83
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(b) ACES.
In July 1997, in order to monetize a portion of the cash value of its
investment in TW Preferred, the Company issued 22.9 million of its unsecured 7%
Automatic Common Exchange Securities (ACES) having an original principal amount
of approximately $1.052 billion. The market value of ACES is indexed to the
market value of TW Common. In July 2000, the ACES will be mandatorily
exchangeable for, at the Company's option, either shares of TW Common at the
exchange rate set forth below or cash with an equal value. The current exchange
rate is as follows:
MARKET PRICE OF TW COMMON EXCHANGE RATE
Below $22.96875 2.0 shares of TW Common
$22.96875 - $27.7922 Share equivalent of $45.9375
Above $27.7922 1.6528 shares of TW Common
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 investment 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 day redemption notice is given. The
redemption price may be paid in cash or in shares of TW Common or a combination
of the two.
By issuing the ACES, the Company effectively eliminated the economic
exposure of its investment in TW securities to decreases in the price of TW
Common below $22.96875. In addition, the Company retained 100% of any increase
in TW Common price up to $27.7922 per share and 17% of any increase in market
price above $27.7922.
Prior to the July 1999 conversion of the TW Preferred, any increase in the
market value of TW Common above $27.7922 was treated for accounting purposes as
an increase in the payment amount of the ACES equal to 83% of the increase in
the market price per share and was recorded by the Company as a non-cash
expense. As a result, the Company recorded in 1999 (prior to conversion), 1998
and 1997 a non-cash, unrealized accounting loss of $435 million, $1.2 billion
and $121 million, respectively (which resulted in an after-tax earnings
reduction of $283 million, or $0.99 per share, $764 million, or $2.69 per share,
and $79 million, or $0.31 per share, respectively). Following the conversion of
TW Preferred into TW Common, changes in the market value of the Company's TW
Common and the related offsetting changes in the liability related to the
Company's obligation under the ACES will be recorded in the Company's Statement
of Consolidated Income.
(c) ZENS.
On September 21, 1999, the Company issued approximately 17.2 million of its
2.0% Zero-Premium Exchangeable Subordinated Notes due 2029 (ZENS) having an
original principal amount of approximately $1.0 billion. At maturity the holders
of the ZENS will receive in cash the higher of the original principal amount of
the ZENS or an amount based on the then-current market value of TW Common, or
other securities distributed with respect to TW Common (one share of TW Common
and such other securities, if any, are referred to as reference shares). Each
ZENS has an original principal amount of $58.25 (the closing market price of the
TW Common on September 15, 1999) and is exchangeable at any time at the option
of the holder for cash equal to 95% (100% in certain cases) of the market value
of the reference shares attributable to one ZENS. The Company pays interest on
each ZENS at an annual rate of 2% plus the amount of any quarterly cash
dividends paid in respect of the quarterly interest period on the reference
shares attributable to each ZENS. Subject to certain conditions, the Company has
the right to defer interest payments from time to time on the ZENS for up to 20
consecutive quarterly periods. As of December 31, 1999, no interest payments on
the ZENS had been deferred.
81
84
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Of the $980 million net proceeds from the offering, the Company used $443
million for general corporate purposes, including repayment of Company
indebtedness. The Company used $537 million of the net proceeds to purchase 9.2
million shares of TW Common, which are classified as trading securities under
SFAS No. 115. Unrealized gains and losses resulting from changes in the market
value of the TW Common are recorded in the Company's Statements of Consolidated
Income.
An increase above $58.25 (subject to certain adjustments) in the market
value per share of TW Common results in an increase in the Company's liability
for the ZENS and is recorded by the Company as a non-cash expense. If the market
value per share of TW Common declines below $58.25 (subject to certain
adjustments), the liability for the ZENS would not decline below the original
principal amount. However, the decline in market value of the Company's
investment in the TW Common would be recorded as an unrealized loss as discussed
above.
Prior to the purchase of additional shares of TW Common on September 21,
1999, the Company owned approximately 8 million shares of TW Common that were in
excess of the 38 million shares needed to economically hedge its ACES
obligation. For the period from July 6, 1999 to the ZENS issuance date, losses
(due to the decline in the market value of the TW Common during such period) on
these 8 million shares were $122 million ($79 million after tax). The 8 million
shares of TW Common combined with the additional 9.2 million shares purchased
are expected to be held to facilitate the Company's ability to meet its
obligation under the ZENS.
The following table sets forth certain summarized financial information of
the Company's investment in TW securities and the Company's ACES and ZENS
obligations.
TW INVESTMENT ACES ZENS
------------- ----------- -----------
(THOUSANDS OF DOLLARS)
Balance at January 1, 1997............................... $ 990,000
Issuance of indexed debt securities...................... $ 1,052,384
Loss on indexed debt securities.......................... 121,402
----------- -----------
Balance at December 31, 1997............................. 990,000 1,173,786
Loss on indexed debt securities.......................... 1,176,211
----------- -----------
Balance at December 31, 1998............................. 990,000 2,349,997
Issuance of indexed debt securities...................... $ 1,000,000
Purchase of TW Common.................................... 537,055
Loss on indexed debt securities.......................... 388,107 241,416
Gain on TW Common........................................ 2,452,406
----------- ----------- -----------
Balance at December 31, 1999............................. $ 3,979,461 $ 2,738,104 $ 1,241,416
=========== =========== ===========
(9) PREFERRED STOCK AND PREFERENCE STOCK
(a) Preferred Stock.
At December 31, 1999 and 1998, the Company had 10,000,000 authorized shares
of cumulative preferred stock, of which 97,397 shares were outstanding. As of
such dates, 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.
82
85
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(b) Preference Stock.
At December 31, 1999 and 1998, Reliant Energy had 10,000,000 authorized
shares of preference stock which were designated and outstanding, as
shown below.
DECEMBER 31, 1999 DECEMBER 31, 1998
------------------------- -------------------------
LIQUIDATION SHARES SHARES SHARES SHARES
VALUE PER SHARE DESIGNATED OUTSTANDING DESIGNATED OUTSTANDING
--------------- ---------- ----------- ---------- -----------
Series A $ 1,000 700,000 700,000
Series B $ 100,000 27,000 17,000 27,000 17,000
Series C $ 100,000 1,575 1,575 1,575
Series D Euro 100,000(1) 5,880 5,880
Series E $ 100,000 3,160 3,160
Series F $ 100,000 2,400 2,400
- ------------
(1) As of December 31, 1999, one U.S. dollar could be exchanged for 1.0062
Euros.
The Series A Preference Stock is issuable in accordance with the Company's
Shareholder Rights Agreement upon the occurrence of certain events. 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, at a purchase price of $42.50 per Fractional Share, subject
to adjustments.
The Series C Preference Stock was redeemed in March 1999. The Series B, D,
E and F Preference Stock are not deemed outstanding for financial reporting
purposes because the sole holders of each series are wholly owned financing
subsidiaries of the Company.
83
86
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(10) LONG-TERM DEBT AND SHORT-TERM BORROWINGS
DECEMBER 31, 1999 DECEMBER 31, 1998
-------------------------- -------------------------
LONG-TERM CURRENT (1) LONG-TERM CURRENT (1)
-----------------------------------------------------
(THOUSANDS OF DOLLARS)
Short-term borrowings:
Commercial paper........................................... $ 1,793,268 $ 1,360,239
Lines of credit (2)........................................ 563,472 150,000
Receivables facilities..................................... 350,000 300,000
Other (3).................................................. 172,471 2,500
----------- -----------
Total short-term borrowings................................... 2,879,211 1,812,739
----------- -----------
Long-term debt:
Reliant Energy
ACES (4)................................................... 2,738,104 $ 2,349,997
ZENS (4)................................................... 1,241,416
Debentures................................................. $ 350,000 350,000
7.88% to 9.38% due 2001 to 2002 as of December 31, 1999
and 1998
First mortgage bonds....................................... 1,261,217 150,000 1,875,732 170,500
4.90% to 9.15% due 2002 to 2027 as of December 31, 1999
4.90% to 9.15% due 2000 to 2027 as of December 31, 1998
Pollution control bonds.................................... 1,045,900 581,385
4.70% to 5.95% due 2011 to 2030 as of December 31, 1999
4.90% to 5.25% due 2015 to 2029 as of December 31, 1998
Notes payable.............................................. 529 31 561 31
12.50% due 2017 as of December 31, 1999 and 1998
Capitalized lease obligations.............................. 12,502 1,229 13,742 1,140
Financing Subsidiaries (directly or indirectly held by
Reliant Energy)
Notes payable.............................................. 525,000
7.12% to 7.40% due 2001 to 2002 as of December 31, 1999
Reliant Energy International, Inc.
Notes payable, 9.00% due 2003 as of December 31, 1999 and
1998..................................................... 92,667 27,905 126,522 22,345
Reliant Energy Power Generation, Inc.
Notes payable.............................................. 70,247
Various market rates due 2002 as of December 31, 1999
N.V. UNA (3)(5)
Debentures................................................. 390,626
3.50% to 9.13% due 2000 to 2010 as of December 31, 1999
Resources Corp. (5)
Convertible debentures..................................... 92,727 104,617
6.0% due 2012
Debentures................................................. 961,545 1,010,919
6.38% to 8.90% due 2003 to 2008 as of December 31, 1999
6.38% to 10.00% due 2003 to 2019 as of December 31, 1998
Medium-term notes.......................................... 150,275 177,591
8.77% to 9.23% maturing 2001 as of December 31, 1999
8.77% to 9.39% maturing 2000 to 2001 as of December 31,
1998
Notes payable.............................................. 223,451 203,116 203,438
7.50% to 9.39% due 2000 as of December 31, 1999
7.50% to 8.88% due 1999 to 2000 as of December 31, 1998
Unamortized discount and premium.............................. 8,075 6,566
----------- ----------- ----------- -----------
Total long-term borrowings.................................... 4,961,310 4,382,136 6,800,748 397,454
----------- ----------- ----------- -----------
Total borrowings........................................... $ 4,961,310 $ 7,261,347 $ 6,800,748 $ 2,210,193
=========== =========== =========== ===========
- ----------------------
(1) Includes amounts due within one year of the date noted.
(2) Includes borrowings which are denominated in Euros as of December 31, 1999.
The assumed exchange rate is 1.0062 Euros per U.S. dollar (exchange rate on
December 31, 1999).
(3) Borrowings are primarily denominated in Dutch guilders. The assumed
exchange rate is 2.19 NLG per U.S. dollar (exchange rate on December 31,
1999).
(4) For additional information regarding ACES and ZENS, see Note 8. As ZENS are
exchangeable at any time at the option of the holders, these notes are
classified as a current portion of long-term debt.
(5) At the respective acquisition dates of UNA and Resources, the debt was
adjusted to fair market value as of that date. Included in unamortized
premium and discount is unamortized premium related to fair value
adjustments
84
87
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
of long-term debt of approximately $48 million and $33 million at December
31, 1999 and 1998, respectively, and is being amortized over the respective
remaining term of the related long-term debt.
(a) Short-term Borrowings.
As of December 31, 1999, the Company has credit facilities, which included
facilities of various financing subsidiaries, UNA and Resources Corp., with
financial institutions which provide for an aggregate of $3.7 billion in
committed credit. The facilities expire as follows: $1.8 billion in 2000, $1.6
billion in 2002 and $0.3 billion in 2003. Interest rates on borrowings are based
on the London interbank offered rate (LIBOR) plus a margin, Euro interbank
deposits plus a margin, a base rate or at a rate determined through a bidding
process. Credit facilities aggregating $1.2 billion are unsecured. These credit
facilities contain covenants and requirements which must be met to borrow funds.
Such covenants are not anticipated to materially restrict the Company from
borrowing funds under such facilities. As of December 31, 1999, unused credit
facilities totaled $1.0 billion. In addition, one of the credit facilities
includes a $65 million sub-facility under which letters of credit may be
obtained. Letters of credit under the sub-facility aggregated $9.3 million as of
December 31, 1999.
The Company sells commercial paper to provide financing for general
corporate purposes. As of December 31, 1999, $1.8 billion of commercial paper
was outstanding. The commercial paper borrowings are supported by various credit
facilities discussed above including a $1.6 billion revolving credit facility
expiring in 2002, a $200 million revolving credit facility expiring in 2000 and
a $350 million revolving credit facility expiring in 2003.
As of December 31, 1999, the Company, through UNA, has $170 million
(assuming an exchange rate of 2.19 NLG per U.S. dollar, exchange rate as of
December 31, 1999) of short-term borrowings arranged via brokers or directly
from financial institutions. These borrowings are used by UNA to meet its
short-term liquidity requirements.
The weighted average interest rate on short-term borrowings in 1999, 1998
and 1997 was 5.84%, 5.77% and 6.12%, respectively.
(b) Long-term Debt.
Maturities of long-term debt and sinking fund requirements for the Company
are approximately $409 million in 2000, $773 million in 2001, $670 million in
2002, $741 million in 2003 and $58 million in 2004. Maturities in 2000 exclude
indexed debt securities (see Note 8) which may be settled with the Company's
investment in TW Common.
Substantially all physical assets used in the conduct of the business and
operations of Electric Operations are subject to liens securing the First
Mortgage Bonds. Sinking fund requirements on the First Mortgage Bonds may be
satisfied by certification of property additions at 100% of the requirements as
defined by the Mortgage and Deed of Trust. Sinking or improvement/replacement
fund requirements for 1999 and prior years have been satisfied by certification
of property additions. The replacement fund requirement to be satisfied in 2000
is approximately $327 million.
At December 31, 1999, Resources Corp. had issued and outstanding $92.7
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. During 1999, Resources Corp. purchased
$12.0 million aggregate principal amount of its Subordinated Debentures.
In November 1998, Resources Corp. issued $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 commencing
in November 2003 if it chooses to exercise the option. The TERM Notes are
unsecured obligations of Resources Corp.
85
88
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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 by the investment bank, Resources
Corp. 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 Corp., 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 Corp. 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 Corp.'s
applicable credit spread at the time of such remarketing.
For the year ended December 31, 1999, 1998 and 1997, the Company
capitalized interest of $19 million, $14 million and $11 million, respectively,
including allowance for funds used during construction related to debt.
During the year ended December 31, 1999, 1998 and 1997, the Company
recorded losses from the extinguishment of debt of $22 million, $20 million and
$17 million, respectively. As these costs will be recovered through regulated
cash flows, these costs have been deferred and a regulatory asset has been
recorded. For further discussion regarding the accounting, see Note 3.
(11) TRUST PREFERRED SECURITIES
In February 1999, Reliant Energy and two newly created and wholly owned
Delaware statutory business trusts (REI Trust I and REI Trust II), registered
$500 million of trust preferred securities and related junior subordinated debt
securities. In February 1999, REI Trust I issued $375 million aggregate amount
of preferred securities to the public. The trust preferred securities accumulate
distributions at a rate of 7.20% payable quarterly in arrears, have a stated
liquidation amount of $25 per preferred security and must be redeemed by March
2048. REI Trust I used the proceeds to purchase $375 million aggregate principal
amount of junior subordinated debentures from the Company having an interest
rate and maturity date that correspond to the distribution rate and mandatory
redemption date of the trust preferred securities. The Company used the proceeds
from the sale of the debentures for general corporate purposes, including the
repayment of short-term debt. Under the registration statement, $125 million of
these securities remain available for issuance. The issuance of all securities
registered by the Company is subject to market and other conditions.
In February 1997, two Delaware statutory business trusts established by the
Company (HL&P Capital Trust I and HL&P Capital Trust II) issued (i) $250 million
of trust preferred securities and (ii) $100 million of capital securities,
respectively. The trust preferred securities have a distribution rate of 8.125%
payable quarterly in arrears, a stated liquidation amount of $25 per trust
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. HL&P Capital Trust I and II used the proceeds to purchase
$350 million aggregate principal amount of subordinated debentures from the
Company having interest rates and maturity dates that correspond to the
distribution rate and the mandatory redemption dates of the trust preferred
securities.
The Company accounts for HL&P Capital Trust I and II and REI Trust I as
wholly owned consolidated subsidiaries. The subordinated debentures are the
trusts' sole asset and their entire operations. The Company has fully and
unconditionally guaranteed, on a subordinated basis, all of HL&P Capital Trust I
and II and REI Trust I's obligations with respect to the preferred securities
and capital securities. The preferred securities and capital securities are
mandatorily redeemable upon the repayment of the subordinated debentures at
their stated maturity or earlier redemption. Subject to certain limitations, the
Company has the option of deferring payments of interest on the subordinated
debentures. During any deferral or event of default, the Company may not pay
dividends on its capital stock. As of December 31, 1999, no interest payments on
the subordinated debentures had been deferred.
86
89
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In June 1996, a Delaware statutory business trust established by Resources
Corp. (Resources Trust) issued $172.5 million of convertible preferred
securities to the public. 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 Resources Trust used the proceeds to purchase $172.5 million of 6.25%
convertible junior subordinated debentures from Resources Corp. having an
interest rate and a maturity date that correspond to the distribution rate and
the mandatory redemption date of the convertible preferred securities. Resources
Corp. accounts for Resources Trust as a wholly owned consolidated subsidiary.
The convertible junior subordinated debentures represent Resources Trust's sole
assets and its entire operations. Resources Corp. has fully and unconditionally
guaranteed, on a subordinated basis, all of Resources Trust's obligations with
respect to the convertible preferred securities. The convertible preferred
securities are mandatorily redeemable upon the repayment of the convertible
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 1999
and 1998, convertible preferred securities aggregating $0.2 million and $15.5
million, respectively, were converted, leaving $0.7 million and $0.9 million
liquidation amount of convertible preferred securities outstanding at December
31, 1999 and 1998, respectively. Subject to certain limitations, Resources Corp.
has the option of deferring payments of interest on the convertible junior
subordinated debentures. During any deferral or event of default, Resources
Corp. may not pay dividends on its common stock to Reliant Energy. As of
December 31, 1999, no interest payments on the debentures had been deferred.
(12) 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, restricted shares,
stock options and stock appreciation rights) to key employees of the Company,
including officers. As of December 31, 1999, 485 current and former employees
participated in the plans. A maximum of approximately 24 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. As of December 31, 1999, the weighted-average remaining contractual
life of outstanding options was 8.3 years. Performance-based stock compensation
issued and restricted shares granted were 294,271 in 1999, 98,413 in 1998 and
704,865 in 1997.
87
90
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Stock option activity for the years 1997 through 1999 is summarized below:
WEIGHTED AVERAGE
NUMBER PRICE AT DATE OF
OF SHARES GRANT OR EXERCISE
-------------- ------------------
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
Options withheld for taxes............................................ (6,854)
Options canceled...................................................... (78,003)
----------
Outstanding at December 31, 1998......................................... 2,945,654 $24.8668
----------
Options granted....................................................... 3,806,051 $26.7372
Options exercised(1).................................................. (83,610) $19.3819
Options canceled...................................................... (205,124)
----------
Outstanding at December 31, 1999......................................... 6,462,971 $25.9937
==========
NUMBER
OF SHARES
------------
December 31, 1999 Exercisable at:
$7.00 - 19.84........................................................................... 147,953
$21.01 - 30.25.......................................................................... 1,202,421
December 31, 1998 Exercisable at:
$7.00 - 19.84........................................................................... 158,695
$20.01 - 35.18.......................................................................... 373,160
December 31, 1997 Exercisable at:
$7.00 - 17.75........................................................................... 302,256
$20.01 - 35.18.......................................................................... 343,048
- ----------
(1) Effective upon the Merger with Resources Corp., each holder of an unexpired
Resources Corp. stock option, whether or not then exercisable, was entitled
to elect to either (i) have all or any portion of their Resources Corp.
stock options canceled and "cashed out" or (ii) have all or any portion of
their Resources Corp. stock options converted to Reliant Energy's stock
options. There were 828,297 Resources Corp. stock options converted into
622,504 of Reliant Energy's stock options at the Merger date. Options
exercised during 1999, 1998 and 1997 included approximately 26,000, 210,000
and 277,000 shares, respectively, related to Resources Corp. stock options
which were converted at the Merger.
In accordance with SFAS No. 123, "Accounting for Stock-Based Compensation,"
the Company applies the rules contained in Accounting Principles Opinion No. 25,
"Accounting for Stock Issued to Employees," and discloses 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.
88
91
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 had been applied:
1999 1998 1997
---------- ---------- -----------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE DATA)
Net income (loss) attributable to common stockholders as reported..... $1,482,081 $ (141,482) $ 420,948
SFAS No. 123 effect................................................... (5,120) (6,383) (2,374)
--------- ---------- ----------
Pro forma net income (loss) attributable to common stockholders....... $1,476,961 $ (147,865) $ 418,574
========== ========== ==========
Pro forma basic earnings per share.................................... $ 5.18 $ (.50) $ 1.66
Pro forma diluted earnings per share.................................. 5.16 (.52) 1.65
The fair value of options granted during 1999, 1998 and 1997 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 5.10%, 5.65% and 6.58% for 1999, 1998 and 1997, respectively,
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 21.23%, 24.01% and 22.06% for 1999, 1998 and 1997, respectively,
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. Prior to 1999, Resources had two noncontributory
retirement plans: (i) the plan which covered the employees of Resources other
than Minnegasco employees and (ii) the plan which covered Minnegasco employees.
The plans provided retirement benefits based on years of service and
compensation. Effective January 1, 1999, the two Resources noncontributory
retirement plans were merged into the Company's plan. The Company's funding
policy is to review amounts annually in accordance with applicable regulations
in order to achieve adequate funding of projected benefit obligations. The
assets of the plan 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 prior
to the plans being merged.
Net pension cost for the Company includes the following components:
YEAR ENDED DECEMBER 31,
---------------------------------------------
1999 1998 1997
-------------- -------------- ---------------
(THOUSANDS OF DOLLARS)
Service cost-- benefits earned during the period...................... $ 33,700 $ 33,436 $ 26,848
Interest cost on projected benefit obligation......................... 88,393 85,132 67,641
Expected return on plan assets........................................ (140,496) (121,196) (86,372)
Net amortization...................................................... (5,361) 6 6
----------- ---------- -----------
Net pension cost............................................ (23,764) (2,622) 8,123
Transfer of obligation to STPNOC...................................... (6,077)
SFAS No. 88-- curtailment expense..................................... 12,947
----------- ---------- -----------
Total pension cost (benefit)................................ $ (23,764) $ (2,622) $ 14,993
=========== ========== ===========
89
92
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 1999 and 1998.
YEAR ENDED DECEMBER 31,
---------------------------
1999 1998
----------- -----------
(THOUSANDS OF DOLLARS)
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of year ......... $ 1,389,444 $ 1,246,582
Service cost .................................. 33,700 33,436
Interest cost ................................. 88,393 85,132
Benefits paid ................................. (97,946) (69,182)
Plan amendments ............................... (161,326)
Actuarial (gain) loss ......................... (181,548) 254,802
----------- -----------
Benefit obligation, end of year ............... $ 1,232,043 $ 1,389,444
=========== ===========
CHANGE IN PLAN ASSETS
Plan asset, beginning of year ................. $ 1,429,882 $ 1,304,023
Benefits paid ................................. (97,946) (69,182)
Employer contributions ........................ 47,406
Actual investment return ...................... 181,177 147,635
----------- -----------
Plan assets, end of year ...................... $ 1,513,113 $ 1,429,882
=========== ===========
RECONCILIATION OF FUNDED STATUS
Funded status ................................. $ 281,070 $ 40,438
Unrecognized transition asset ................. (5,401) (7,205)
Unrecognized prior service cost ............... (137,950) (148,400)
Unrecognized actuarial loss ................... 11,742 240,864
----------- -----------
Net amount recognized ......................... $ 149,461 $ 125,697
=========== ===========
ACTUARIAL ASSUMPTIONS
Discount rate ................................. 7.5% 6.5%
Rate of increase in compensation levels ....... 3.5 - 5.5% 3.5 - 5.5%
Expected long-term rate of return on assets ... 10.0% 10.0%
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 Merger date.
In 1998, the Company's board of directors approved the amendment and
restatement of the retirement plan, 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 for 1999 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 energy services 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,
"Employers' Accounting for Pensions" as amended. As a result of the January 1,
1999 amendment and restatement, which is reflected in the December 31, 1998
disclosure, the Company's projected benefit obligation declined $161 million.
The actuarial gains and losses are due to changes in certain actuarial
assumptions.
90
93
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
In addition to the noncontributory plans discussed above, the Company
maintains a non-qualified plan which allows participants to retain the benefits
to which they would have been entitled under the Company's noncontributory plan
except for the federally mandated limits on such benefits or on the level of
salary on which such benefits may be calculated. Prior to 1999, Resources
maintained certain similar non-qualified plans. Effective January 1, 1999,
Resources' non-qualified plans were merged into Reliant Energy's non-qualified
plan. The related benefit obligation at December 31, 1999 and 1998, was $28
million and $26 million, respectively. Expense of approximately $5 million
associated with these non-qualified plans was recorded each year during 1999,
1998 and 1997, respectively.
(c) Savings Plan.
Reliant Energy 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, pre-tax or after-tax, up to a maximum of 16% of
compensation. In 1999, the savings plan was amended so that Reliant Energy now
matches 75% to 125% of the first 6% of each employee's compensation contributed,
subject to a vesting schedule, based on certain performance goals achieved by
the Company. Through 1998, Reliant Energy matched 70% of the first 6% of each
employee's compensation contributed, subject to a vesting schedule.
Substantially all of Reliant Energy's match is invested in Reliant Energy common
stock.
In October 1990, Reliant Energy amended its savings plan to add a leveraged
Employee Stock Ownership Plan (ESOP) component. Reliant Energy 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 Reliant Energy. Shares of Reliant Energy common stock are
released from the encumbrance of the ESOP loan based on the proportion of debt
service paid during the period.
The Company recognizes benefit expense for the ESOP equal to the fair value
of the ESOP shares committed to be released. 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 ESOP shares were as follows:
DECEMBER 31,
-------------------------------
1999 1998
------------ ------------
Allocated shares transferred/distributed from the savings plan.............. 2,115,536 1,916,508
Allocated shares............................................................ 5,967,159 5,171,613
Unearned shares............................................................. 10,679,489 11,674,063
------------ ------------
Total original ESOP shares............................................. 18,762,184 18,762,184
============ ============
Fair value of unearned ESOP shares.......................................... $244,293,311 $374,270,460
Prior to April 1, 1999, Resources had an employee savings plan that covered
substantially all Resources employees other than Reliant Energy Minnegasco
employees. Under the terms of the Resources savings plan, employees could
contribute up to 12% of total compensation in 1998 and 1997, which contributions
up to 6% were matched by the Company. Beginning January 1, 1999, employees could
contribute up to 16% of total compensation, which contribution up to 6% were
matched by the Company. Prior to April 1, 1999, the Reliant Energy Minnegasco
employees were covered by a savings plan, the terms of which were somewhat
similar to the Resources savings plan. Effective April 1, 1999, the Resources
and the Reliant Energy Minnegasco savings plans were merged into the Company's
savings plan.
91
94
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The Company's savings plan benefit expense was $26 million, $25 million and
$22 million in 1999, 1998, and 1997, respectively.
(d) Postretirement Benefits.
The Company records the liability for postretirement 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 Merger
date.
As provided in the 1995 Rate Case Settlement, Reliant Energy HL&P 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, excluding Reliant Energy HL&P and
Reliant Energy Minnegasco, will continue funding its postretirement benefits on
a pay-as-you-go basis.
Net postretirement benefit cost for the Company includes the following
components:
YEAR ENDED DECEMBER 31,
---------------------------------
1999 1998 1997
--------- -------- --------
(THOUSANDS OF DOLLARS)
Service cost-- benefits earned during the period ....... $ 5,073 $ 8,060 $ 8,927
Interest cost on projected benefit obligation .......... 26,259 17,270 14,176
Expected (return) loss on plan assets .................. (8,986) (5,977) (4,515)
Net amortization ....................................... 14,629 3,298 4,011
-------- -------- --------
Net postretirement benefit cost ................... 36,975 22,651 22,599
Transfer of obligation to STPNOC ....................... 173
-------- -------- --------
Total cost ........................................ $ 36,975 $ 22,651 $ 22,772
======== ======== ========
Following are reconciliations of the Company's beginning and ending
balances of its postretirement benefit plans benefit obligation, plan assets and
funded status for 1999 and 1998.
92
95
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
YEAR ENDED DECEMBER 31,
------------------------
1999 1998
---------- ---------
(THOUSANDS OF DOLLARS)
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of year .................................. $ 409,811 $ 269,531
Service cost ........................................................... 5,073 8,060
Interest cost .......................................................... 26,259 17,270
Benefits paid .......................................................... (21,846) (20,662)
Participant contributions .............................................. 3,633 2,960
Acquisitions ........................................................... 12,414
Plan amendments ........................................................ 98,918
Actuarial (gain) loss .................................................. (40,242) 33,734
--------- ---------
Benefit obligation, end of year ........................................ $ 395,102 $ 409,811
========= =========
CHANGE IN PLAN ASSETS
Plan asset, beginning of year .......................................... $ 84,068 $ 56,340
Benefits paid .......................................................... (21,846) (20,662)
Employer contributions ................................................. 32,559 32,889
Participant contributions .............................................. 3,633 2,960
Actual investment return ............................................... 6,414 12,541
--------- ---------
Plan assets, end of year ............................................... $ 104,828 $ 84,068
========= =========
RECONCILIATION OF FUNDED STATUS
Funded status .......................................................... $(290,274) $(325,743)
Unrecognized transition (asset) or obligation .......................... 134,917 144,046
Unrecognized prior service cost ........................................ 91,976 98,918
Unrecognized actuarial (gain) loss ..................................... (97,758) (61,530)
--------- ---------
Net amount recognized at end of year ................................... $(161,139) $(144,309)
========= =========
ACTUARIAL ASSUMPTIONS
Discount rate .......................................................... 7.5% 6.5%
Rate of increase in compensation levels ................................ 3.5 - 5.5% 3.5 - 5.5%
Expected long-term rate of return on assets ............................ 10.0% 10.0%
Health care cost trend rates - Under 65 ................................ 5.8% 6.0%
Health care cost trend rates - 65 and over ............................. 6.2% 6.7%
The assumed health care rates gradually decline to 5.4% for both medical
categories by 2001.
If the health care cost trend rate assumptions were increased by 1%, the
accumulated postretirement benefit obligation as of December 31, 1999 would be
increased by approximately 4.9%. The annual effect of the 1% increase on the
total of the service and interest costs would be an increase of approximately
4.6%. If the healthcare cost trend rate assumptions were decreased by 1%, the
accumulated postretirement benefit obligation as of December 31, 1999 would be
decreased by approximately 4.8%. The annual effect of the 1% decrease on the
total of the service and interest costs would be a decrease of 4.4%.
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 Company will continue to reflect the costs of the retiree medical plan
according to the provisions of SFAS No. 106 as amended. As a result of the
January 1, 1999 amendment, which is reflected in
93
96
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
the December 31, 1998 disclosure, the Company's benefit obligation increased $99
million. The plan amendment had no impact on 1998 expense.
The actuarial gains and losses are 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 $11 million in 1999 and were not material in 1998 and 1997.
(13) INCOME TAXES
The Company's current and deferred components of income tax expense
(benefit) are as follows:
YEAR ENDED DECEMBER 31,
--------------------------------------------------
1999 1998 1997
------------ ------------ ------------
(THOUSANDS OF DOLLARS)
Current ......................................................... $ 297,490 $ 439,322 $ 199,011
Deferred ........................................................ 601,627 (469,754) 7,363
------------ ------------ ------------
Income tax expense (benefit) .................................... $ 899,117 $ (30,432) $ 206,374
============ ============ ============
A reconciliation of the federal statutory income tax rate to the effective
income tax rate is below.
YEAR ENDED DECEMBER 31,
--------------------------------------------------
1999 1998 1997
------------ ------------ ------------
(THOUSANDS OF DOLLARS)
Income (loss) before income taxes .............................. $ 2,564,848 $ (171,524) $ 627,484
Preferred dividends of subsidiary .............................. 2,255
------------ ------------ ------------
Total ..................................................... 2,564,848 (171,524) 629,739
Federal statutory rate ......................................... 35% 35% 35%
------------ ------------ ------------
Income taxes at statutory rate ................................. 897,697 (60,033) 220,409
------------ ------------ ------------
Net addition (reduction) in taxes resulting from:
State income taxes, net of federal income tax benefit ....... 24,764 16,853 (9)
Amortization of investment tax credit ....................... (20,551) (20,123) (19,777)
Excess deferred taxes ....................................... (4,543) (4,011) (5,570)
Difference between book and tax depreciation
for which deferred taxes have not been normalized ......... 37,069 27,466
Equity dividend exclusion ................................... (980) (5,075)
Equity income - foreign affiliates .......................... (789) (23,241) (17,011)
Goodwill .................................................... 18,045 18,049 7,242
Other - net ................................................. (15,506) 5,985 (1,301)
------------ ------------ ------------
Total ..................................................... 1,420 29,601 (14,035)
------------ ------------ ------------
Income tax expense (benefit) ................................... $ 899,117 $ (30,432) $ 206,374
============ ============ ============
Effective rate ................................................. 35.1% 17.7% 32.8%
UNA Tax Holiday. Under 1999 Dutch tax law relating to the Dutch electricity
industry, UNA qualifies for a zero tax rate through December 31, 2001. The tax
holiday applies only to the Dutch income earned by UNA. Beginning January 1,
2002, UNA will be subject to Dutch corporate income tax at standard statutory
rates.
94
97
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
Permanent Reinvestment. As of December 31, 1999 the Company had
approximately $29 million of foreign income which is considered to be
permanently reinvested in foreign operations. Of this amount, $3 million is
related to the Company's operations in Argentina and $26 million is related to
the Company's operations in the Netherlands.
Following are the Company's tax effects of temporary differences between
the carrying amounts of assets and liabilities in the financial statements and
their respective tax bases:
DECEMBER 31,
---------------------------------
1999 1998
------------ ------------
(THOUSANDS OF DOLLARS)
Deferred tax assets:
Current:
Unrealized loss on indexed debt securities .............................. $ 674,497
------------ ------------
Non-current:
Alternative minimum tax credit carryforwards ............................ 34,536 $ 38,659
Employee benefits ....................................................... 98,388 153,367
Disallowed plant cost - net ............................................. 58,058 56,219
Unrealized loss on indexed debt securities .............................. 454,165
Operating loss carryforwards ............................................ 38,954 23,178
Foreign income .......................................................... 49,850 32,685
Cumulative foreign currency translation adjustments ..................... 40,906 11,764
Contingent liabilities associated with discontinuance of SFAS No. 71 .... 73,639
Other ................................................................... 114,845 46,797
Valuation allowance ..................................................... (19,139) (8,591)
------------ ------------
Total non-current deferred tax assets ................................. 490,037 808,243
------------ ------------
Total deferred tax assets - net ...................................... $ 1,164,534 $ 808,243
------------ ------------
Deferred tax liabilities:
Current:
Unrealized gain on Time Warner investment ............................... $ 1,090,088
------------ ------------
Non-current:
Depreciation ............................................................ 2,318,958 $ 2,090,014
Regulatory assets - net ................................................. 379,814 609,694
Capitalized taxes, employee benefits and removal costs .................. 47,907 60,099
Unrealized gain on Time Warner investment ............................... 222,942
Deferred state income taxes ............................................. 68,952 70,000
Deferred gas costs ...................................................... 32,361 13,237
Other ................................................................... 93,664 106,293
------------ ------------
Total non-current deferred tax liabilities ............................ 2,941,656 3,172,279
------------ ------------
Total deferred tax liabilities ....................................... 4,031,744 3,172,279
------------ ------------
Accumulated deferred income taxes - net ......................... $ 2,867,210 $ 2,364,036
============ ============
Tax Attribute Carryforwards. At December 31, 1999, the Company had
approximately $492 million of state net operating losses available to offset
future state taxable income through the year 2019. In addition, the Company has
approximately $28 million of federal alternative minimum tax credits which are
available to reduce future federal income taxes payable over an indefinite
period and approximately $1 million of state alternative minimum tax credits
that are available to reduce future state income taxes payable through the year
2002. The valuation allowance reflects a net increase of $11 million in 1999.
This net increase results from a reassessment of the Company's usage of state
tax attributes, including the future ability to use state net operating loss and
alternative
95
98
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
minimum tax credit carryforwards offset by changes in valuation
allowances provided for expiring state net operating loss carryforwards.
Tax Refund Case. In July 1990, the Company paid approximately $105 million
to the Internal Revenue Service (IRS) following an IRS audit of 1983 and 1984
federal income tax returns. In November 1991, the Company filed a refund suit in
the U.S. Court of Federal Claims seeking the return of $52 million of tax and
$36 million of accrued interest, plus interest on both of those amounts accruing
after July 1990. In September 1997, the United States Court of Appeals upheld a
lower court ruling that the Company was due a refund of federal income taxes
during 1983 and 1984 attributable to fuel cost overrecoveries that subsequently
were refunded to Reliant Energy HL&P's customers. In February 1998, the Company
received a refund of approximately $142 million in taxes and interest paid 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).
(14) COMMITMENTS AND CONTINGENCIES
(a) Commitments.
The Company has various commitments for capital expenditures, fuel,
purchased power 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. Wholesale Energy has entered into commitments associated with various
non-rate regulated generating projects aggregating $324 million along with
various generating equipment purchases aggregating $318 million for delivery
from 2000 to 2001 that are anticipated to be used for future development
projects. The Company's 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.
Reliant Energy HL&P 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 that extend
through 2011 are approximately $187 million in 2000, $188 million in 2001 and
$188 million in 2002. Purchase commitments related to lignite mining and lease
agreements, natural gas purchases and storage contracts, and purchased power are
not material to the operations of the Company.
Currently Reliant Energy HL&P is allowed recovery of these costs through
base rates for electric service. As of December 31, 1999, certain of these
contracts are above market. The Company anticipates that stranded cost
associated with these obligations will be recoverable through the stranded cost
recovery mechanisms contained in the Legislation. For information regarding the
Legislation, see Note 3.
(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
1999, 1998
96
99
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
and 1997, savings generated for CPS' account were approximately $14 million, $14
million and $22 million, respectively. Through December 31, 1999, cumulative
earnings generated for CPS' account were approximately $64 million.
(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, $50 million and $34 million, respectively,
to ANR. Resources recorded $41 million as a liability reflecting ANR's 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 ANR. 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 at
December 31, 1999 which primarily relate to Resources principally consisting of
rental agreements for building space, data processing equipment and vehicles,
including major work equipment (in millions):
2000 .................................... $ 16
2001 .................................... 15
2002 .................................... 10
2003 .................................... 8
2004 .................................... 7
2005 and beyond ......................... 25
----
Total .............................. $ 81
----
(f) Letters of Credit.
At December 31, 1999, the Company had letters of credit totaling
approximately $14 million under which it is obligated to reimburse drawings, if
any.
(g) Cross Border Leases.
During the period from 1994 through 1997, under cross border lease
transactions, UNA leased several of its power plants and related equipment and
turbines to non-Netherlands based investors and concurrently leased the
facilities back under sublease arrangements with remaining terms as of December
31, 1999 of two to 25 years. Such transactions involve the Company providing to
a foreign investor an ownership right in (but not necessarily title to) an
asset, with a leaseback of the asset. The net proceeds to UNA of the
transactions are being amortized to income over the lease terms. At December 31,
1999, the deferred gain on these transactions totaled $87 million assuming an
exchange rate of 2.19 NLG per U.S. dollar (the exchange rate on December 31,
1999). UNA utilized proceeds from the head lease transactions to prepay sublease
obligations as well as provide a source for payment of end of term purchase
options and other financial undertakings. The leased property remains on the
financial statements of UNA and continues to be depreciated. In the case of
early termination of the cross border leases, UNA would be contingently liable
for certain payments to the sublessors, which at December 31, 1999 are estimated
to be $254 million. Prior to March 1, 2000, UNA will be required by some of the
lease agreements to obtain standby letters of credit in favor of the sublessors
in the event of early termination in the amount of $205 million (assumes an
exchange rate of 2.19 NLG per U.S. dollar, the exchange rate on December 31,
1999). Commitments for such letters of credit have been obtained as of December
31, 1999.
97
100
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 judgment to that effect from a court in
Galveston County, Texas. Based on this judgment 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 matter will have a material adverse effect on the Company's
financial condition, results of operations or cash flows.
From time to time the Company has received notices from regulatory
authorities or others regarding its status as a PRP 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 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.
(i) Other.
The Company is 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 respective financial statements, if any, from the
disposition of these matters will not be material.
98
101
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 of all similarly situated cities in Reliant
Energy HL&P's service area, against the Company and Houston Industries Finance
Inc. (formerly a wholly owned subsidiary of the Company) alleging underpayment
of municipal franchise fees. Plaintiffs in essence claim that they are entitled
to 4% of all receipts of any kind for business conducted within city
limits or with the use of city rights-of-way. Plaintiffs advance their claims
notwithstanding their failure to assert such claims over the previous four
decades. Because all of the franchise ordinances affecting Electric Operations
expressly impose fees only on the Company's own receipts and only from sales of
electricity for consumption within a city, the Company regards plaintiffs'
allegations as spurious and is vigorously contesting the case. The plaintiffs'
pleadings assert that their damages exceed $250 million. The 269th Judicial
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 were denied. A jury
trial of the remaining individual claims of the three named cities (but not the
entire class) began on February 14, 2000 and is expected to conclude by the end
of March 2000. The extent to which issues resolved in this trial may affect the
claims of the other class member cities cannot be determined until final
judgment is rendered. The Company believes that it is very unlikely that
resolution of this case will have a material adverse effect on the Company's
financial condition, results of operations or cash flows.
(15) ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
DECEMBER 31,
-----------------------------------------------------------
1999 1998
--------------------------- ---------------------------
CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE
----------- ----------- ----------- -----------
(THOUSANDS OF DOLLARS)
Financial assets:
Investment in Time Warner securities.......................... $ 3,979,461 $ 3,979,461 $ 990,000 $ 2,843,585
Energy derivatives - non-trading ............................. 2,823
Foreign currency swaps ....................................... 6,011
Financial liabilities:
Long-term debt (excluding capital leases) .................... 9,329,715 9,212,871 7,183,320 7,470,785
Trust securities ............................................. 705,272 598,690 342,232 367,649
Interest rate swaps .......................................... 38 92 109 3,160
Energy derivatives - non-trading ............................. 1,105 8,166
The fair values of cash and cash equivalents, investments in debt and
equity security classified as "available-for-sale" and "trading" in accordance
with SFAS No. 115 (except for Time Warner securities), and notes payable are
estimated to be equivalent to carrying amounts and have been excluded from the
above table. 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
are marked-to-market at December 31, 1999 and 1998 (see Note 5). Therefore, they
are stated at fair value and are excluded from the table.
99
102
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
(16) EARNINGS PER SHARE
The following table reconciles numerators and denominators of the
Company's basic and diluted earnings per share calculations:
FOR THE YEAR ENDED DECEMBER 31,
-----------------------------------------------------
1999 1998 1997
------------ ---------- ----------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
Basic EPS calculation:
Income (loss) before extraordinary item and preferred
dividends........................................................ $ 1,665,731 $ (141,092) $ 421,110
Less: Preferred dividends.......................................... 389 390 162
------------ ---------- ----------
Income (loss) attributable to common stockholders before
extraordinary item.............................................. 1,665,342 (141,482) 420,948
Extraordinary item................................................. (183,261)
------------ ---------- ----------
Net income (loss).................................................. $ 1,482,081 $ (141,482) $ 420,948
============ ========== ==========
Weighted average shares outstanding................................ 285,040 284,095 253,599
Basic EPS:
Income (loss) before extraordinary item............................ $ 5.84 $ (.50) $ 1.66
============ ========== ==========
Extraordinary item................................................. $ (.64) $ $
============ ========== ==========
Net income (loss).................................................. $ 5.20 $ (.50) $ 1.66
============ ========== ==========
Diluted EPS calculation:
Net income (loss).................................................. $ 1,482,081 $ (141,482) $ 420,948
Plus: Income impact of assumed conversions
Interest on 6 1/4% convertible trust preferred securities.......... 30 668
------------ ---------- ----------
Total Effect....................................................... $ 1,482,111 $ (141,482) $ 421,616
============ ========== ==========
Assuming dilution
Weighted average shares outstanding................................... 285,040 284,095 253,599
Plus: Incremental shares from assumed conversions (1)
Stock options...................................................... 400 89
Restricted stock................................................... 701
6 1/4% convertible trust preferred securities...................... 23 510
------------ ---------- ----------
Weighted average shares assuming dilution.......................... 286,164 284,095 254,198
============ ========== ==========
Diluted EPS:
Income (loss) before extraordinary item............................ $ 5.82 $ (.50) $ 1.66
============ ========== ==========
Extraordinary item................................................. $ (.64) $ $
============ ========== ==========
Net income (loss).................................................. $ 5.18 $ (.50) $ 1.66
============ ========== ==========
- --------
(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.
For the year ended December 31, 1999, the computation of diluted EPS
excludes purchase options for 433,915 shares of common stock that have exercise
prices (ranging from $28.72 to $32.22 per share) greater than the $27.58 per
share average market price for the period.
100
103
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
(17) UNAUDITED QUARTERLY INFORMATION
Summarized quarterly financial data is as follows:
YEAR ENDED DECEMBER 31, 1999
-----------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
----------- ----------- ----------- -----------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
Revenues ........................................................ $ 2,642,904 $ 3,657,828 $ 4,947,192 $ 4,054,886
Operating income ................................................ 187,665 291,122 494,288 267,439
Extraordinary item, net of tax .................................. 183,261
Net income (loss) attributable to common stockholders ........... (209,789) 74,664 1,689,990 (72,784)
Basic earnings (loss) per share (2)
Extraordinary item, net of tax ............................... (.64)
Net income (loss) attributable to common stockholders ........ (.74) .26 5.92 (.26)
Diluted earnings (loss) per share (2)
Extraordinary item, net of tax ............................... (.64)
Net income (loss) attributable to common stockholders ........ (.74) .26 5.90 (.26)
YEAR ENDED DECEMBER 31, 1998
-----------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
----------- ----------- ----------- -----------
(THOUSANDS OF DOLLARS, EXCEPT PER SHARE AMOUNTS)
Revenues (1) .................................................... $ 2,631,322 $ 2,736,626 $ 3,465,487 $ 2,655,029
Operating income (1) ............................................ 281,735 454,208 506,994 222,881
Net income (loss) attributable to common stockholders (1) ....... (30,115) 41,484 251,709 (404,560)
Basic and diluted earnings (loss) per share (2) ................. (.11) .15 .89 (1.42)
- ----------
(1) Includes retroactive adjustment for change in accounting for energy price
risk management and trading activities to mark-to-market accounting for
the first, second and third quarters of 1998 (see Note 1(o)).
(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.
(18) REPORTABLE SEGMENTS
The Company's determination of reportable segments considers the strategic
operating units under which the Company manages sales, allocates resources and
assesses performance of various products and services to wholesale or retail
customers in differing regulatory environments. Financial information for
Resources and UNA are included in the segment disclosures only for periods
beginning on their respective acquisition dates. 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.
The Company has identified the following reportable segments: Electric
Operations, Natural Gas Distribution, Interstate Pipelines, Wholesale Energy,
Reliant Energy Europe, Reliant Energy Latin America and Corporate. For
description of the financial reporting segments, see Note 1(a). Financial data
for business segments, products and services and geographic areas are as
follows:
101
104
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
RELIANT
ELECTRIC NATURAL GAS INTERSTATE WHOLESALE ENERGY
OPERATIONS DISTRIBUTION PIPELINES ENERGY EUROPE
---------- ------------ ---------- --------- ---------
(THOUSANDS OF DOLLARS)
As of and for the year ended
December 31, 1999:
Revenues from external
customers .................. $ 4,483,126 $ 1,895,358 $ 121,514 $ 7,688,960 $ 152,865
Intersegment revenues ...... 1,202 153,580 260,317
Depreciation and
amortization ............... 666,968 132,424 49,127 25,323 20,737
Operating income ........... 981,006 124,863 113,018 45,308 32,049
Total assets ............... 9,940,685 3,386,596 2,211,842 2,773,070 3,247,290
Equity investments in and
advances to unconsolidated
subsidiaries ............... 78,041
Expenditures for
long-lived assets .......... 572,625 205,545 30,131 529,805 834,300
As of and for the year ended
December 31, 1998:
Revenues from external
customers .................. 4,350,275 1,877,185 126,988 4,289,006
Intersegment revenues ...... 1,167 155,508 167,152
Depreciation and
amortization ............... 663,740 130,658 44,025 18,204
Operating income ........... 1,002,409 144,447 128,328 59,170
Total assets ............... 10,404,447 3,141,762 2,050,636 1,535,007
Equity investments in and
advances to unconsolidated
subsidiaries ............... 42,252
Expenditures for
long-lived assets .......... 433,474 161,735 59,358 363,174
As of and for the year ended
December 31, 1997:
Revenues from external
customers .................. 4,251,243 920,125 49,655 1,288,357
Intersegment revenues ...... 505 58,678 76,301
Depreciation and
amortization ............... 582,040 52,374 19,088 2,633
Operating income ........... 985,484 56,842 31,978 912
Expenditures for
long-lived assets .......... 236,977 61,078 16,304 14,038
RELIANT
ENERGY
LATIN RECONCILING
AMERICA CORPORATE ELIMINATIONS CONSOLIDATED
--------- --------- ----------- -----------
(THOUSANDS OF DOLLARS)
As of and for the year ended
December 31, 1999:
Revenues from external
customers .................. $ 79,717 $ 881,270 $15,302,810
Intersegment revenues ...... 73,648 $ (488,747)
Depreciation and
amortization ............... 5,817 10,726 911,122
Operating income ........... (23,021) (32,709) 1,240,514
Total assets ............... 1,155,500 4,645,403 (1,139,450) 26,220,936
Equity investments in and
advances to unconsolidated
subsidiaries ............... 944,169 1,022,210
Expenditures for
long-lived assets .......... 93,296 89,840 2,355,542
As of and for the year ended
December 31, 1998:
Revenues from external
customers .................. 258,945 586,065 11,488,464
Intersegment revenues ...... 97,181 (421,008)
Depreciation and
amortization ............... 3,820 9,646 870,093
Operating income ........... 181,707 (50,243) 1,465,818
Total assets ............... 1,242,689 1,679,876 (915,895) 19,138,522
Equity investments in and
advances to unconsolidated
subsidiaries ............... 1,009,348 1,051,600
Expenditures for
long-lived assets .......... 435,077 28,077 1,480,895
As of and for the year ended
December 31, 1997:
Revenues from external
customers .................. 92,028 276,817 6,878,225
Intersegment revenues ...... 34,853 (170,337)
Depreciation and
amortization ............... 3,470 5,769 665,374
Operating income ........... 19,510 (39,680) 1,055,046
Expenditures for
long-lived assets .......... 231,528 1,426,323 1,986,248
102
105
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
YEAR ENDED DECEMBER 31,
--------------------------------------------
1999 1998 1997
------------ ------------ ------------
(THOUSANDS OF DOLLARS)
RECONCILIATION OF OPERATING INCOME TO NET INCOME
(LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS:
Operating income ..................................... $ 1,240,514 $ 1,465,818 $ 1,055,046
Interest income - IRS refund ......................... 56,269
Time Warner dividend income .......................... 25,770 41,250 41,340
Interest expense ..................................... (511,474) (509,601) (395,085)
Unrealized gain on Time Warner investment ............ 2,452,406
Unrealized loss on indexed debt securities ........... (629,523) (1,176,211) (121,402)
Distribution on trust securities ..................... (51,220) (29,201) (26,230)
Income tax benefit (expense) ......................... (899,117) 30,432 (206,374)
Other income (expense) ............................... 37,986 36,031 17,384
Extraordinary item, net of tax ....................... (183,261)
------------ ------------ ------------
Net income (loss) attributable to common stockholders $ 1,482,081 $ (141,482) $ 420,948
============ ============ ============
REVENUES BY PRODUCTS AND SERVICES:
Retail power sales ................................... $ 4,483,126 $ 4,350,275 $ 4,251,243
Retail gas sales ..................................... 2,669,393 2,372,086 1,156,618
Wholesale energy and energy related sales ............ 7,808,401 4,248,181 1,271,400
Gas transport ........................................ 157,530 167,812 66,265
Income from Latin America investments ................ 79,717 258,945 92,028
Energy products and services ......................... 104,643 91,165 40,671
------------ ------------ ------------
Total ................................................ $ 15,302,810 $ 11,488,464 $ 6,878,225
============ ============ ============
REVENUES AND LONG-LIVED ASSETS BY GEOGRAPHIC AREAS:
REVENUES:
US ................................................... $ 14,953,546 $ 11,229,519 $ 6,786,197
Latin America ........................................ 79,717 258,945 92,028
Netherlands .......................................... 152,865
Other ................................................ 116,682
------------ ------------ ------------
Total ................................................ $ 15,302,810 $ 11,488,464 $ 6,878,225
============ ============ ============
LONG-LIVED ASSETS:
US ................................................... $ 15,664,491 $ 16,273,392
Latin America ........................................ 1,116,928 1,195,849
Netherlands .......................................... 3,186,146
Other ................................................ 102 110
------------ ------------
Total ................................................ $ 19,967,667 $ 17,469,351
============ ============
103
106
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(19) SUBSEQUENT EVENTS
(a) Acquisition of Remaining Shares of UNA.
On March 1, 2000, the Company purchased the remaining 48% of the shares of
UNA for $975 million. Funds for the March 1, 2000 acquisition were obtained, in
part, from a Euro 600 million (approximately $596 million) three-year term loan
facility established in February 2000. See Note 2 for additional information
regarding the acquisition of UNA.
(b) Sithe Power Generating Assets Acquisition.
In February 2000, the Company signed a definitive agreement to purchase
from Sithe Energies, Inc. non-rate regulated power generating assets and sites
located in Pennsylvania, New Jersey and Maryland having a net generating
capacity of more than 4,200 megawatts for an aggregate purchase price of $2.1
billion, subject to certain adjustments. The acquisition is expected to close in
the second quarter of 2000 and is subject to obtaining certain regulatory
approvals and satisfying other closing conditions. The acquisition will be
accounted for as a purchase.
(c) Other Financings.
In February 2000, a financing subsidiary of the Company borrowed $500
million under a $650 million revolving credit facility that was established in
February 2000 and terminates on April 30, 2000. Proceeds were used by the
financing subsidiary to purchase Series G Preference Stock of Reliant Energy.
The Company used the proceeds from the sale of Preference Stock for general
corporate purposes, including the repayment of indebtedness. In addition, in
March 2000, the Company borrowed $150 million under a revolving credit facility
that was established in February 2000 and terminates on May 31, 2000. The
Company used the proceeds from the borrowing for general corporate purposes,
including the repayment of indebtedness.
(d) Treasury Stock Purchases.
During the period from January 1, 2000 through March 1, 2000, the Company
purchased 1,183,800 shares of its common stock for approximately $27 million at
an average price of $23.07 per share.
(e) Natural Gas Distribution and Interstate Pipelines (Unaudited).
In March 2000, the Company announced that it had retained an investment
banking firm to assist it in evaluating strategic alternatives, including
divestiture, for (i) two of its natural gas distribution divisions, Reliant
Energy Arkla and Reliant Energy Minnegasco, (ii) its Interstate Pipelines'
operations and (iii) its natural gas gathering and pipeline services operations.
104
107
INDEPENDENT AUDITORS' REPORT
Reliant Energy, Incorporated:
We have audited the accompanying consolidated balance sheets of Reliant
Energy, Incorporated and its subsidiaries (the "Company") as of December 31,
1999 and 1998, and the related statements of consolidated income, consolidated
comprehensive income, consolidated cash flows and consolidated stockholders'
equity for each of the three years in the period ended December 31, 1999. Our
audits also included the Company's financial statement schedule listed in Item
14(a)(2). 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, 1999 and 1998, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1999 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
March 1, 2000
105
108
ITEM 7. MANAGEMENT'S NARRATIVE ANALYSIS OF THE RESULTS OF OPERATIONS OF RELIANT
ENERGY RESOURCES CORP. AND ITS CONSOLIDATED SUBSIDIARIES.
The following narrative and analysis should be read in combination with the
consolidated financial statements and notes of Reliant Energy Resources Corp.
(Resources Corp.) and its subsidiaries (collectively, Resources) contained in
Item 8 of the Form 10-K of Resources Corp. Prior to February 1999, Resources
Corp. conducted business under the name "NorAm Energy Corp."
RELIANT ENERGY RESOURCES CORP.
In August 1997, the former parent corporation (Former Parent) of Reliant
Energy, Incorporated (Reliant Energy) merged with and into Reliant Energy, and
NorAm Energy Corp. (Former Resources) merged with and into Resources Corp.
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.
The Merger was recorded under the purchase method of accounting with assets
and liabilities of Former Resources reflected at their estimated fair values,
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."
Because Resources Corp. is a wholly owned subsidiary of Reliant Energy,
Resources' determination of reportable segments considers the strategic
operating units under which Reliant Energy manages sales, allocates resources
and assesses performance of various products and services to wholesale or retail
customers in differing regulatory environments. Reliant Energy has identified
the following reportable segments: Electric Operations, Natural Gas
Distribution, Interstate Pipelines, Wholesale Energy, Reliant Energy Europe,
Reliant Energy Latin America and Corporate. Of these segments, the following
operations are conducted by Resources:
o Natural Gas Distribution
o Interstate Pipelines
o Wholesale Energy (which includes wholesale energy trading, marketing
and risk management services in North America and domestic natural gas
gathering operations of the Wholesale Energy segment but excludes the
operations of Reliant Energy Power Generation, Inc., a wholly owned
subsidiary of Reliant Energy)
o Reliant Energy Europe (which includes the energy trading and marketing
operations initiated in the fourth quarter of 1999 in the Netherlands
and other countries in Europe but excludes N.V. UNA, a Dutch power
company), and
o Certain Corporate operations
In March 2000, Reliant Energy announced that it had retained an investment
banking firm to assist it in evaluating strategic alternatives, including
divesture, for (i) two of its natural gas distribution divisions, Reliant Energy
Arkla and Reliant Energy Minnegasco, (ii) its Interstate Pipelines operations
and (iii) its natural gas gathering and pipeline services operations, including
divestiture.
Resources Corp. meets the conditions specified in General Instruction
I(1)(a) and (b) to Form 10-K and is thereby permitted to use the reduced
disclosure format for wholly owned subsidiaries of reporting companies
106
109
specified therein. Accordingly, Resources Corp. has omitted from this Combined
Form 10-K 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 party
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 Corp. 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 1999, 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 Form 10-K 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,
among other things, the actions of various federal and state governmental
authorities having jurisdiction over rates charged by Resources, 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 -- Competition -- Other Operations" and "--
Environmental Expenditures -- Mercury Contamination" in Item 7 of Reliant
Energy's 1999 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:
o The impact of the amortization of newly-recognized goodwill
o The amortization of the revaluation of long-term debt
o The removal of the amortization previously associated with the pension
and postretirement obligations, and
o The deferred income tax expense associated with these adjustments
The total effect of these purchase accounting adjustments for the twelve
months ended December 31, 1999 and 1998 and the five months ended December 31,
1997, was a decrease to net income of $34 million, $26 million and $9 million,
respectively. 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.
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
1999, 1998 and 1997 and (ii) an unaudited pro forma basis for 1997 as if the
Merger had taken place at the beginning of 1997. These results do not
necessarily reflect the results which would have been obtained if the Merger had
actually occurred on January 1, 1997 or the results that may be expected in the
future.
107
110
The following table sets forth selected financial and operating data on an
actual and unaudited pro forma basis for the years ended December 31, 1999, 1998
and 1997, followed by a discussion of significant variances in period-to-period
results:
SELECTED FINANCIAL RESULTS
ACTUAL PRO FORMA (1)
----------------------------------------------------------------------------
YEAR YEAR FIVE MONTHS SEVEN MONTHS YEAR
ENDED ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, DECEMBER 31, JULY 31, DECEMBER 31,
1999 1998 1997 1997 1997
------------ ------------ ------------ ------------ ------------
(THOUSANDS OF DOLLARS)
Operating Revenues ............. $ 10,543,545 $ 6,758,412 $ 2,526,182 $ 3,313,591 $ 5,839,773
Operating Expenses ............. 10,245,862 6,448,107 2,434,282 3,141,295 5,597,716
Operating Income Before Merger
Transaction Costs ............ 297,683 310,305 91,900 172,296 242,057
Merger Transaction Costs (2) ... 1,144 17,256
Operating Income ............... 297,683 310,305 90,756 155,040 242,057
Interest Expense, net .......... 119,492 111,337 47,490 78,660 112,996
Distributions on Trust Preferred
Securities ................... 357 632 279 6,317 1,479
Other (Income), net ............ (11,138) (7,318) (2,243) (7,210) (9,453)
Income Tax Expense ............. 88,771 111,830 24,383 31,398 71,093
Extraordinary (Gain) ........... -- -- -- (237)
------------ ------------ ------------ ------------ ------------
Net Income ................... $ 100,201 $ 93,824 $ 20,847 $ 46,112 $ 65,942
============ ============ ============ ============ ============
- ------------
(1) Unaudited pro forma results reflect purchase adjustments as if the Merger
had occurred on January 1, 1997.
(2) For expenses associated with the completion of the Merger, see Note 1(l) to
Resources' Consolidated Financial Statements.
1999 (Actual) Compared to 1998 (Actual). Resources' net income for 1999 was
$100 million compared to net income of $94 million in 1998. The $6 million
increase was primarily due to a significant increase in operating income of
Wholesale Energy's trading and marketing operations and a decrease in the
effective tax rate, partially offset by decreased earnings in the Natural Gas
Distribution and Interstate Pipelines segments and increased general insurance
liability expense. Although results of Wholesale Energy's trading and marketing
operations significantly improved, it continues to incur higher operating
expenses relating to staffing and personnel to support its increased sales and
marketing efforts.
Operating income decreased in 1999 by $13 million, or 4%, from 1998. The
decline was primarily due to increased operating expenses, in particular
employee benefit expenses, at the Natural Gas Distribution and Interstate
Pipelines segments and increased general liability insurance expense. The
decline was partially offset by increased operating income of Wholesale Energy's
trading and marketing operations.
Resources' operating revenues for 1999 were $10.5 billion compared to $6.8
billion for 1998. The $3.8 billion increase, or 56%, was primarily due to
increased wholesale trading and marketing revenues from increased trading
volumes for power, natural gas and oil, as well as higher sale prices for these
commodities.
Resources' operating expenses for 1999 were $10.2 billion compared to $6.4
billion in 1998. The $3.8 billion, or 59%, increase was primarily attributable
to an increase in volumes and cost of purchased power, natural gas and oil, as
discussed above. In addition, operating expenses also increased due to increased
employee benefit expenses for the Natural Gas Distribution and Interstate
Pipelines segments, increased operating expenses to support increased sales and
marketing of the Wholesale Energy trading and marketing operations (as discussed
above) and increased general insurance liability expense.
Resources' effective tax rate in 1999 was 47% compared to 54% in 1998. This
decrease was primarily due to a decrease in state income taxes resulting from
lower state taxable income in 1999 as compared to 1998.
108
111
1998 (Actual) Compared to 1997 (Actual). Resources' consolidated net income for
1998 was $94 million compared to consolidated net income of $67 million in 1997.
The $27 million, or 40%, 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 the 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
revaluation at the time of the Merger.
Operating income increased in 1998 by $65 million, or 26%, 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.
Resources' operating revenues for 1998 were $6.8 billion as compared to
$5.8 billion in 1997. The $918 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 $383 million, principally due to
warmer weather.
Resources' operating expenses for 1998 were $6.4 billion compared to $5.6
billion in 1997. The $854 million increase, or 15%, 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 the Natural Gas Distribution segment because
of lower volumes resulting from the warmer weather.
Resources' effective tax rate was 54% in 1998 compared to 46% in 1997. This
increase is primarily due to increased state income taxes and non-deductible
goodwill amortization. State income taxes increased as a result of higher
combined state taxable income in 1998 as compared to 1997.
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 $28 million increase, or 42%, in earnings for 1998 as compared to
pro forma 1997 earnings was due to increased operating income from several
business segments, as discussed below, partially offset by a decrease in
operating income from the Natural Gas Distribution segment due to the effects of
warmer weather.
Operating income increased in 1998 by $68 million, or 28%, 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 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 at
Wholesale Energy. 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 operating revenues for 1998 were $6.8 billion compared to pro
forma operating revenues of $5.8 billion in 1997. Resources operating expenses
for 1998 were $6.4 billion compared to pro forma operating expense of $5.6
billion in 1997. These increases are due to the same factors discussed above in
the comparison of 1998 and 1997 actual results.
109
112
IMPACT OF YEAR 2000 ISSUES
Resources' total direct cost of resolving the Year 2000 issues was
approximately $6 million. 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 -- Impact of the Year 2000 Issue and Other System Implementation Issues"
in Item 7 of Reliant Energy's 1999 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 Reliant Energy's 1999 Form 10-K, for discussion of certain new
accounting issues that affect Resources.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
For information regarding Resources' exposure to interest rate, equity
market, foreign currency and commodity price risk, see "Quantitative and
Qualitative Disclosures About Market Risk--Interest Rate Risk," "--Equity Market
Risk," "--Foreign Currency Exchange Rate Risk," and "--Energy Commodity Price
Risk" in Item 7A of Reliant Energy's Report on Form 10-K, which information, to
the extent it relates to Resources, is incorporated herein by reference.
110
113
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)
CURRENT RESOURCES FORMER RESOURCES
--------------------------------------------------------------------------
TWELVE MONTHS TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, 1999 DECEMBER 31, 1998 DECEMBER 31, 1997 JULY 31, 1997
----------------- ------------------ ----------------- ----------------
REVENUES .............................................. $ 10,543,545 $ 6,758,412 $ 2,526,182 $ 3,313,591
EXPENSES:
Natural gas and purchased power .................... 9,307,445 5,603,973 2,063,986 2,623,670
Operation and maintenance .......................... 636,549 539,985 241,823 359,582
Depreciation and amortization ...................... 198,676 191,891 78,087 84,901
Taxes other than income taxes ...................... 103,192 112,258 50,386 73,142
Merger transaction costs ........................... 1,144 17,256
------------ ------------ ------------ ------------
10,245,862 6,448,107 2,435,426 3,158,551
------------ ------------ ------------ ------------
OPERATING INCOME ...................................... 297,683 310,305 90,756 155,040
------------ ------------ ------------ ------------
OTHER INCOME (EXPENSE):
Interest expense, net .............................. (119,492) (111,337) (47,490) (78,660)
Distribution on trust preferred securities ......... (357) (632) (279) (6,317)
Other, net ......................................... 11,138 7,318 2,243 7,210
------------ ------------ ------------ ------------
(108,711) (104,651) (45,526) (77,767)
------------ ------------ ------------ ------------
INCOME BEFORE INCOME TAXES AND
EXTRAORDINARY ITEM ................................. 188,972 205,654 45,230 77,273
Income Tax Expense .................................... 88,771 111,830 24,383 31,398
------------ ------------ ------------ ------------
INCOME BEFORE EXTRAORDINARY ITEM ...................... 100,201 93,824 20,847 45,875
Extraordinary Gain on Early Retirement of
Debt, net of income taxes of $128 .................. 237
------------ ------------ ------------ ------------
NET INCOME ............................................ $ 100,201 $ 93,824 $ 20,847 $ 46,112
============ ============ ============ ============
See Notes to Resources' Consolidated Financial Statements
111
114
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
STATEMENTS OF CONSOLIDATED STOCKHOLDER'S EQUITY AND COMPREHENSIVE INCOME
(THOUSANDS OF DOLLARS)
COMMON STOCK (1) RETAINED
--------------------------- PAID IN EARNINGS
SHARES AMOUNT CAPITAL (DEFICIT)
------------ ----------- ------------ ------------
FORMER RESOURCES:
Stockholders' Equity at December 31, 1996 ... 137,908,173 $ 86,193 $ 1,001,053 $ (286,703)
Net Income .................................. 46,112
Cash Dividends:
Common stock - $0.14 per share ............ (19,281)
Change in Market Value of Marketable
Equity Securities, net tax of ($3,329) ....
Conversion of Trust Preferred Securities .... 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 (259,872)
------------ ----------- ------------ ------------
CURRENT RESOURCES (POST MERGER):
Adjustments due to Merger:
Eliminate Former Resources Balances ....... (149,683,962) (93,552) (1,138,274) 259,872
Capital Contribution from Parent ............ 1,000 1 2,463,831
Net Income .................................. 20,847
Change in Market Value of Marketable
Equity Securities, net of tax of $3,193 ...
Comprehensive Income ........................
------------ ----------- ------------ ------------
Balance at December 31, 1997 ................ 1,000 1 2,463,831 20,847
------------ ----------- ------------ ------------
Net Income .................................. 93,824
Change in Market Value of Marketable
Equity Securities, net of tax of $5,877 ...
Comprehensive Income ........................
------------ ----------- ------------ ------------
Balance at December 31, 1998 ................ 1,000 1 2,463,831 114,671
------------ ----------- ------------ ------------
Net Income .................................. 100,201
Foreign currency translation adjustments,
net of tax of ($16) .......................
Change in Market Value of Marketable
Equity Securities, net of tax of $373 .....
Comprehensive Income ........................
------------ ----------- ------------ ------------
Balance at December 31, 1999 ................ 1,000 $ 1 $ 2,463,831 $ 214,872
============ ============ ============ ============
ACCUMULATED
OTHER TOTAL TOTAL
COMPRE- STOCK- COMPRE-
HENSIVE HOLDER'S HENSIVE
INCOME EQUITY INCOME
------------ ----------- ------------
FORMER RESOURCES:
Stockholders' Equity at December 31, 1996 ... $ 5 $ 800,548
Net Income .................................. 46,112 $ 46,112
Cash Dividends:
Common stock - $0.14 per share ............ (19,281)
Change in Market Value of Marketable
Equity Securities, net tax of ($3,329) .... 5,874 5,874 5,874
Conversion of Trust Preferred Securities .... 138,568
Other Issuances ............................. 6,012 ------------
Comprehensive Income ........................ 51,986
------------ ----------- ============
Balance at July 31, 1997 .................... 5,879 977,833
------------ -----------
CURRENT RESOURCES (POST MERGER):
Adjustments due to Merger:
Eliminate Former Resources Balances ....... (5,879) (977,833)
Capital Contribution from Parent ............ 2,463,832
Net Income .................................. 20,847 20,847
Change in Market Value of Marketable
Equity Securities, net of tax of $3,193 ... (5,634) (5,634) (5,634)
Comprehensive Income ........................ ------------
15,213
------------ ----------- ============
Balance at December 31, 1997 ................ (5,634) 2,479,045
------------ -----------
Net Income .................................. 93,824 93,824
Change in Market Value of Marketable
Equity Securities, net of tax of $5,877 ... (10,370) (10,370) (10,370)
-----------
Comprehensive Income ........................ 83,454
------------ ----------- ============
Balance at December 31, 1998 ................ (16,004) 2,562,499
------------ -----------
Net Income ................................ 100,201 100,201
Foreign currency translation adjustments,
net of tax of ($16) ....................... 30 30 30
Change in Market Value of Marketable
Equity Securities, net of tax of $373 ..... (1,224) (1,224) (1,224)
------------
Comprehensive Income ........................ $ 99,007
------------ ----------- ============
Balance at December 31, 1999 ................ $ (17,198) $ 2,661,506
============ ===========
- ------------
(1) $0.625 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).
See Notes to Resources' Consolidated Financial Statements
112
115
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF DOLLARS)
DECEMBER 31, DECEMBER 31,
1999 1998
---------- ----------
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ....................................... $ 81,347 $ 26,576
Accounts and notes receivable, principally customer ............. 980,560 682,552
Unbilled revenue ................................................ 150,961 145,131
Accounts and notes receivable - affiliated companies, net ....... 145,191
Materials and supplies, at average cost ......................... 35,121 33,947
Fuel, gas and petroleum products ................................ 80,135 161,085
Price risk management assets .................................... 435,336 265,203
Prepayments and other current assets ............................ 46,666 39,234
---------- ----------
Total current assets .......................................... 1,810,126 1,498,919
---------- ----------
PROPERTY, PLANT AND EQUIPMENT - NET ............................... 2,973,882 2,815,028
---------- ----------
OTHER ASSETS:
Goodwill, net ................................................... 1,983,004 2,050,386
Prepaid pension asset ........................................... 110,626 102,034
Price risk management assets .................................... 148,722 21,414
Deferred debits ................................................. 186,437 119,754
---------- ----------
Total other assets ............................................ 2,428,789 2,293,588
---------- ----------
TOTAL ASSETS ...................................................... $7,212,797 $6,607,535
========== ==========
LIABILITIES AND STOCKHOLDER'S EQUITY
CURRENT LIABILITIES:
Current portion of long-term debt ............................... $ 223,451 $ 203,438
Short-term borrowings ........................................... 534,584 300,000
Accounts payable, principally trade ............................. 776,546 574,276
Accounts and notes payable - affiliated companies, net .......... 95,601
Taxes accrued ................................................... 48,266 55,415
Interest accrued ................................................ 27,965 36,197
Customer deposits ............................................... 33,255 36,985
Price risk management liabilities ............................... 424,324 227,652
Other ........................................................... 119,111 172,616
---------- ----------
Total current liabilities............... 2,283,103 1,606,579
---------- ----------
DEFERRED CREDITS:
Accumulated deferred income taxes ............................... 532,725 497,762
Price risk management liabilities ............................... 117,437 40,532
Payable under capacity lease agreement .......................... 41,000 41,000
Benefit obligations ............................................. 161,144 158,762
Other ........................................................... 194,284 185,955
---------- ----------
Total deferred credits ........................................ 1,046,590 924,011
---------- ----------
LONG-TERM DEBT .................................................... 1,220,631 1,513,289
---------- ----------
COMMITMENTS AND CONTINGENCIES (NOTE 8)
RESOURCES OBLIGATED MANDATORILY REDEEMABLE CONVERTIBLE PREFERRED
SECURITIES OF SUBSIDIARY TRUST HOLDING SOLELY JUNIOR SUBORDINATED
DEBENTURES OF RESOURCES ......................................... 967 1,157
---------- ----------
STOCKHOLDER'S EQUITY .............................................. 2,661,506 2,562,499
---------- ----------
Total Liabilities and Stockholder's Equity ................ $7,212,797 $6,607,535
========== ==========
See Notes to Resources' Consolidated Financial Statements
113
116
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
STATEMENTS OF CONSOLIDATED CASH FLOWS
(THOUSANDS OF DOLLARS)
CURRENT RESOURCES FORMER RESOURCES
--------------------------------------------------------------
TWELVE MONTHS TWELVE MONTHS FIVE MONTHS SEVEN
ENDED ENDED ENDED MONTHS
DECEMBER 31, DECEMBER 31, DECEMBER 31, ENDED
1999 1998 1997 JULY 31, 1997
------------- ------------- ------------ ---------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income ............................................. $ 100,201 $ 93,824 $ 20,847 $ 46,112
Adjustments to reconcile net income to net cash provided
by (used in) operating activities:
Depreciation and amortization ....................... 198,676 191,891 78,087 84,901
Deferred income taxes ............................... 58,055 31,810 36,770 14,589
Extraordinary gain .................................. (237)
Changes in other assets and liabilities:
Accounts and notes receivable-net ................. (303,838) 141,565 (351,179) 313,586
Accounts receivable/payable, affiliates ........... (1,343) 45,670 (10,106)
Inventories ....................................... 79,776 (102,125) (2,250) 9,980
Other current assets .............................. (16,020) 9,422 7,357 (8,843)
Accounts payable .................................. 202,270 (115,010) 125,971 (224,590)
Interest and taxes accrued ........................ (9,206) 13,454 (13,402) (19,996)
Other current liabilities ......................... (41,463) (12,531) 42,284 (22,633)
Net price risk management assets .................. (23,864) (18,433)
Restricted deposits ............................... (55,667) 42,630 (11,096) 3,396
Other-net ......................................... (52,512) (36,208) 24,373 3,007
----------- ----------- ----------- -----------
Net cash provided by (used in) operating
activities ................................... 135,065 285,959 (52,344) 199,272
----------- ----------- ----------- -----------
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of Former Resources, net of cash acquired ..... (1,422,672)
Capital expenditures ................................... (288,760) (253,972) (93,414) (88,638)
Other, net ............................................. (12,770) 8,068 (1,079) (6,424)
----------- ----------- ----------- -----------
Net cash used in investing activities .......... (301,530) (245,904) (1,517,165) (95,062)
----------- ----------- ----------- -----------
CASH FLOWS FROM FINANCING ACTIVITIES:
Cash portion of capital contribution from
Reliant Energy ...................................... 1,426,067
Payments of long-term debt ............................. (255,293) (249,253) (175,312) (230,667)
Proceeds from long-term debt ........................... 812,849 150,000
Increase (decrease) in short-term borrowings - net ..... 234,584 (390,000) 341,500 (1,500)
Increase (decrease) in notes with affiliates - net ..... 242,135 (202,800) 22,100
Common and preferred stock dividends ................... (19,281)
Other, net ............................................. (190) (19,957) (9,164) (27,348)
----------- ----------- ----------- -----------
Net cash provided by (used in) financing activities .... 221,236 (49,161) 1,605,191 (128,796)
----------- ----------- ----------- -----------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS ...... 54,771 (9,106) 35,682 (24,586)
CASH AND CASH EQUIVALENTS AT BEGINNING OF THE PERIOD ...... 26,576 35,682 27,981
----------- ----------- ----------- -----------
CASH AND CASH EQUIVALENTS AT END OF THE PERIOD ............ $ 81,347 $ 26,576 $ 35,682 $ 3,395
=========== =========== =========== ===========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash Payments:
Interest (net of amounts capitalized) .................. $ 142,399 $ 111,217 $ 55,672 $ 67,100
Income taxes ........................................... 45,540 46,522 714 20,900
See Notes to Resources' Consolidated Financial Statements
114
117
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, 1999
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) Nature of Operations.
Reliant Energy Resources Corp. (Resources Corp.), formerly NorAm Energy
Corp., together with its subsidiaries (collectively, Resources) distributes
natural gas, transports natural gas through its interstate pipelines and
provides energy services including gathering, storage and wholesale energy
marketing, trading and risk management services. Resources Corp. is a Delaware
corporation and a wholly owned subsidiary of Reliant Energy, Incorporated
(Reliant Energy).
Resources' natural gas distribution operations (Natural Gas Distribution)
are conducted by three unincorporated divisions: Reliant Energy Entex, Reliant
Energy Minnegasco and Reliant Energy Arkla. Resources' interstate pipeline
operations (Interstate Pipelines) are conducted by two wholly owned
subsidiaries, Reliant Energy Gas Transmission Company (REGT) and Mississippi
River Transmission Corporation (MRT). Resources' wholesale energy marketing,
trading and risk management activities in North America are conducted primarily
by Reliant Energy Services, Inc. (Reliant Energy Services) and gas gathering
activities are conducted by Reliant Energy Field Services, Inc. (Reliant Energy
Field Services). Resources' European energy trading and marketing activities are
conducted by Reliant Energy Trading & Marketing B.V., a wholly owned subsidiary.
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.
(b) Merger with Reliant Energy, Incorporated.
In August 1997, the former parent corporation (Former Parent) of Reliant
Energy, merged with and into Reliant Energy, and NorAm Energy Corp. (Former
Resources) merged with and into Resources Corp. 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.
The Merger was recorded under the purchase method of accounting with
assets and liabilities of Former Resources reflected at their estimated fair
values, resulting in a "new basis" of accounting. The 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.
115
118
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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, Resources' unaudited pro
forma net income for 1997 would have been $66 million. 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
January 1, 1997.
(c) Regulatory Assets and Regulation.
Resources applies the accounting policies established in SFAS No. 71,
"Accounting for the Effects of Certain Types of Regulation" (SFAS No. 71) to the
accounts of its Natural Gas Distribution operations and to MRT. Resources'
Natural Gas Distribution operations are subject to regulation at the state or
municipal level and the Interstate Pipelines operations of MRT are subject to
regulation by the Federal Energy Regulatory Commission. As of December 31, 1999
and 1998, Resources had recorded as deferred debits and other deferred credits
approximately $4 million and $12 million, respectively, of net regulatory
assets.
If, as a result of changes in regulation or competition, Resources' ability
to recover these assets and liabilities would not be assured, then pursuant to
SFAS No. 101, "Regulated Enterprises Accounting for the Discontinuation of
Application of SFAS No. 71" and SFAS No. 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets to be Disposed Of," Resources would
be required to write off or write down such regulatory assets and liabilities.
(d) Principles of Consolidation.
Resources' Consolidated Financial Statements include the accounts of
Resources Corp. and its wholly owned subsidiaries. All significant intercompany
transactions and balances are eliminated in consolidation.
(e) Property, Plant and Equipment and Goodwill .
Property, plant and equipment includes the following:
DECEMBER 31,
-------------------------------
1999 1998
------------- -------------
(THOUSANDS OF DOLLARS)
PROPERTY, PLANT AND EQUIPMENT:
Natural gas ............................ $ 1,941,668 $ 1,686,159
Interstate pipelines ................... 1,330,969 1,302,829
Other .................................. 25,841 13,976
------------- -------------
Total .............................. 3,298,478 3,002,964
Less accumulated depreciation .......... 324,596 187,936
------------- -------------
Property, plant and equipment - net .... $ 2,973,882 $ 2,815,028
============= =============
116
119
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Property, plant and equipment have been revalued to estimated fair market
value as of the Merger date in accordance with the purchase method of
accounting, and depreciated or amortized on a straight-line basis over their
estimated useful lives. Repair and maintenance costs are expensed. The cost of
utility plant and equipment retirements is charged to accumulated depreciation.
Goodwill is being amortized on a straight-line basis over 40 years.
Resources had $128 million and $75 million accumulated goodwill amortization at
December 31, 1999 and 1998, respectively. Resources will periodically compare
the carrying value of its goodwill to the anticipated undiscounted future net
cash flows 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.
Depreciation is computed using the straight-line method based on economic
lives or a regulatory mandated method. The range of plant and equipment
depreciable lives for natural gas, interstate pipelines and other property is 5
to 50 years, 5 to 75 years and 3 to 20 years, respectively. Depreciation expense
for 1999 was $143 million compared to $137 million for 1998 and $132 million for
1997 of which $56 million relates to the five months ended December 31, 1997.
Approximately $53 million and $54 million of goodwill was amortized during 1999
and 1998, respectively. Approximately $30 million of goodwill was amortized
during 1997 of which $22 million represents amortization related to the Merger
and was incurred during the period from the acquisition date through December
31, 1997. Other amortization expense was $3 million, $1 million and $1 million
in 1999, 1998 and 1997, respectively.
(g) Fuel, Gas and Petroleum Products.
Gas inventory (primarily using the average cost method) was $78.5 million
and $79.9 million at December 31, 1999 and 1998, respectively, and is valued at
the lower of cost or market. Fuel stock and petroleum products, principally
heating oil, were $1.6 million and $81.2 million at December 31, 1999 and 1998,
respectively, and are used in the trading operations and are marked-to-market in
connection with the price risk management activities as discussed in Note 2.
(h) Revenues.
Resources records natural gas sales under the accrual method, whereby
unbilled natural gas sales are estimated and recorded each month. Interstate
Pipelines records revenues as transportation services are provided. In 1998,
Resources adopted mark-to-market accounting for its energy price risk management
and trading activities (see Notes 1(q) and 2).
(i) 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.
(j) Income Taxes.
Reliant Energy files a consolidated federal income tax return in which
Resources is included as of the acquisition date. The Company follows a policy
of comprehensive interperiod income tax allocation. The Company uses the
liability method of accounting for deferred income taxes and measures deferred
income taxes for all significant income tax temporary differences. For
additional information regarding income taxes, see Note 7.
117
120
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(k) Investments in Marketable Equity Securities.
The Company 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 Resources' Consolidated Balance Sheets as deferred
debits and any unrealized gain or loss, net of tax, as a separate component of
stockholder's equity and other comprehensive income. At December 31, 1999 and
1998, the accumulated unrealized loss, net of tax, relating to these equity
securities was approximately $17.2 million and $16.0 million, respectively.
(l) Merger Transaction Costs.
"Merger transaction costs" include expenses associated with completion of
the Merger, principally consisting of investment banking and legal fees.
(m) 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 $21.3 million and $17.6 million at December 31, 1999 and 1998,
respectively.
(n) Related Party Transactions.
Reliant Energy has established a "money fund" through which Resources can
borrow or invest on a short-term basis. Net investments of Resources, included
in accounts and notes receivable-affiliated companies, totaled $181 million at
December 31, 1998. Interest income on such investments was $6.1 million and $5.1
million for the year ended December 31, 1999 and 1998, respectively. Net
borrowings of Resources, included in accounts and notes payables-affiliated
companies, totaled $62 million at December 31, 1999. Interest expense on such
borrowings was $0.1 million and $0.2 million for the years ended December 31,
1999 and 1998, respectively. Interest income and expense on such investments and
borrowing for 1997 were not material.
Reliant Energy Services supplies natural gas to, purchases electricity for
resale from, and provides marketing and risk management services to unregulated
power plants in deregulated markets, acquired or operated by Reliant Energy
Power Generation, Inc., a wholly owned subsidiary of Reliant Energy, or its
subsidiaries. During 1999 and 1998, the sales and services to Reliant Energy and
its affiliates totaled $197 million and $96 million, respectively. Purchases of
electricity from Reliant Energy and its affiliates were $116 million and $29
million in 1999 and 1998, respectively. Sales and purchases to/from Reliant
Energy and its affiliates were not material in 1997.
Reliant Energy provides certain corporate services to Resources which are
allocated to Resources or direct billed to Resources, including management
support, financial and tax accounting, information system support, treasury
support, legal services, regulatory support and other general services. During
1999, 1998 and 1997, the allocated and direct billed corporate services totaled
$34 million, $29 million and $19 million, respectively.
As of December 31, 1999 and 1998, net accounts payable to Reliant Energy
and its subsidiaries, which are not owned by Resources, was $34 million and $36
million, respectively.
Certain subsidiaries of Resources Corp. have entered into office rental
agreements with Reliant Energy. In 1999 and 1998, Resources paid $1.7 million
and $0.9 million of rent expense to Reliant Energy for each respective year.
118
121
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(o) Foreign Currency Adjustments.
Assets and liabilities of Resources Corp.'s foreign subsidiaries 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 stockholder's equity and other
comprehensive income.
(p) Reclassifications and Use of Estimates.
Certain amounts from the previous years have been reclassified to conform
to the 1999 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,
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.
(q) Change in Accounting Principle.
In the fourth quarter of 1998, Resources adopted mark-to-market accounting
for all of its energy price risk management and trading activities. 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 and options contracts, at each balance sheet
date. Such amounts are recorded as price risk management assets and liabilities.
The realized and unrealized gains and losses are recorded as a component of
operating revenues. Resources has applied mark-to-market accounting
retroactively to January 1, 1998. There was no material cumulative effect
resulting from this accounting change.
Resources adopted Emerging Issues Task Force Issue 98-10, "Accounting for
Contracts Involved in Energy Trading and Risk Management Activities" (EITF
98-10) in 1999. The adoption of EITF Issue 98-10 had no material impact on the
consolidated financial statements.
(r) New Accounting Pronouncement.
Effective January 1, 2001, Resources is required to adopt Statement of
Financial Accounting Standards No. 133, "Accounting for Derivative Instruments
and Hedging Activities" as amended (SFAS No. 133), which establishes accounting
and reporting standards for derivative instruments, including certain hedging
instruments embedded in other contracts and for hedging activities. Resources is
in the process of determining the effect of adopting SFAS No. 133 on its
consolidated financial statements.
(2) DERIVATIVE FINANCIAL INSTRUMENTS
(a) Price Risk Management and Trading Activities.
Resources offers energy price risk management services primarily related to
natural gas, electricity, crude oil and refined products, weather, coal and
certain air emissions regulatory credits. Resources provides these services by
utilizing a variety of derivative financial instruments, including fixed and
variable-priced physical forward contracts, fixed and variable-priced swap
agreements and options traded in the over-the-counter financial markets and
exchange-traded energy futures and option contracts (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
119
122
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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, Resources applied hedge accounting to certain physical
commodity activities that qualified for hedge accounting. In 1998, Resources
adopted mark-to-market accounting for all of its price risk management and
trading activities. Accordingly, since 1998, such Trading Derivatives are
recorded at fair value with realized and unrealized gains (losses) recorded as a
component of revenues. The recognized, unrealized balance is included in price
risk management assets/liabilities (See Note 1(q)).
The notional quantities, maximum terms and the estimated fair value of
Trading Derivatives at December 31, 1999 and 1998 are presented below (volumes
in billions of British thermal units equivalent (Bbtue) and dollars in
millions):
VOLUME-FIXED VOLUME-FIXED MAXIMUM
PRICE PAYOR PRICE RECEIVER TERM (YEARS)
------------- -------------- -------------
1999
Natural gas ....................... 936,716 939,416 9
Electricity ....................... 251,592 248,176 10
Crude oil and refined products .... 143,857 144,554 3
1998
Natural gas ....................... 937,264 977,293 9
Electricity ....................... 122,950 124,878 3
Crude oil and refined products .... 205,499 204,223 3
AVERAGE FAIR
FAIR VALUE VALUE (A)
----------------------------- -----------------------------
ASSETS LIABILITIES ASSETS LIABILITIES
------------ ------------ ------------ ------------
1999
Natural gas ....................... $ 319 $ 299 $ 302 $ 283
Electricity ....................... 131 98 103 80
Crude oil and refined products .... 134 145 127 132
------------ ------------ ------------ ------------
$ 584 $ 542 $ 532 $ 495
============ ============ ============ ============
1998
Natural gas ....................... $ 224 $ 212 $ 124 $ 108
Electricity ....................... 34 33 186 186
Crude oil and refined products .... 29 23 21 17
------------ ------------ ------------ ------------
$ 287 $ 268 $ 331 $ 311
============ ============ ============ ============
- ---------
(a) Computed using the ending balance of each quarter.
In addition to the fixed-price notional volumes above, Resources also has
variable-priced agreements, as discussed above, totaling 3,797,824 and 1,702,977
Bbtue as of December 31, 1999 and 1998, 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 tables above at December 31, 1999 and
December 31, 1998 have been recognized in income. The fair value as of December
31, 1999 and 1998 was estimated using quoted prices where available and
considering the liquidity of the market for the Trading Derivatives. The prices
and fair values are subject to significant changes based on changing market
conditions.
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
120
123
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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' 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 Resources as of December 31, 1999 and 1998.
DECEMBER 31, 1999 DECEMBER 31, 1998
-------------------------- -------------------------
INVESTMENT INVESTMENT
GRADE (1) TOTAL GRADE (1) TOTAL
---------- ---------- ---------- ----------
(MILLIONS OF DOLLARS)
Energy marketers ............................ $ 172 $ 183 $ 103 $ 124
Financial institutions ...................... 119 119 62 62
Gas and electric utilities .................. 184 186 47 48
Oil and gas producers ....................... 6 30 7 8
Industrials ................................. 4 5 2 3
Independent power producers ................. 4 6 1 1
Others ...................................... 64 67 45 47
---------- ---------- ---------- ----------
Total .................................. $ 553 596 $ 267 293
========== ==========
Credit and other reserves ................... (12) (6)
---------- ----------
Energy price risk management assets (2) ..... $ 584 $ 287
========== ==========
- ----------
(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) As of December 31, 1999, Resources had no credit risk exposure to any
single counterparty that represents greater than 5% of price risk
management assets.
(b) Non-Trading Activities.
To reduce the risk from market fluctuations in the revenues derived from
electric power, natural gas and related transportation, Resources enters 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
and to protect natural gas distribution earnings against unseasonably warm
weather during peak gas heating months, although usage to date for this purpose
has not been material. Resources applies hedge accounting with respect to its
derivative financial instruments utilized in non-trading activities.
For transactions involving Energy Derivatives, hedge accounting is applied
only if the derivative (i) reduces the 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.
Unrealized changes in the market value of Energy Derivatives utilized as
hedges are not generally recognized in Resources' Statements of Consolidated
Income until the underlying hedged transaction occurs. Once it becomes
121
124
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, 1999, Resources was fixed-price payors and fixed-price
receivers in Energy Derivatives covering 33,108 billion British thermal units
(Bbtu) and 5,481 Bbtu of natural gas, respectively. At December 31, 1998,
Resources was fixed-price payors and fixed-price receivers in Energy Derivatives
covering 42,498 Bbtu and 3,930 Bbtu of natural gas, respectively. Also, at
December 31, 1999 and 1998, Resources was a party to variable-priced Energy
Derivatives totaling 44,958 Bbtu and 21,437 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' 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' 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 has 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 enters into such contracts primarily with counterparties
having a minimum Standard & Poor's or Moody's rating of BBB- or Baa3,
respectively. For long-term arrangements, Resources periodically reviews 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 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 losses 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.
Reliant Energy's policies prohibit the use of leveraged financial
instruments.
Reliant Energy has established a Risk Oversight Committee, comprised of
corporate and business segment officers that oversees all commodity price and
credit risk activities, including Resources' trading, marketing and risk
122
125
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
management activities. The Committee's duties are to establish Reliant Energy's
and Resources' commodity risk policies, allocate risk capital within limits
established by Reliant Energy's board of directors, approve trading of new
products and commodities, monitor risk positions and ensure compliance with
Reliant Energy's risk management policies and procedures and trading limits
established by Reliant Energy's board of directors.
(3) CAPITAL STOCK
Resources' Direct Stock Purchase Plan and Dividend Reinvestment Plan were
suspended and canceled in connection with the Merger.
(4) LONG-TERM AND SHORT-TERM BORROWINGS
----------------------------- -----------------------------
DECEMBER 31, 1999 DECEMBER 31, 1998
------------ ------------ ------------ ------------
LONG-TERM CURRENT (1) LONG-TERM CURRENT (1)
------------ ------------ ------------ ------------
(THOUSANDS OF DOLLARS)
Short-term borrowings:
Receivables facilities ...................................... $ 350,000 $ 300,000
Commercial paper ............................................ 184,584
------------ ------------
Total short-term borrowings ................................... 534,584 300,000
------------ ------------
Long-term debt: (2)
Convertible debentures ...................................... $ 92,727 $ 104,617
6.0% due 2012
Debentures .................................................. 961,545 1,010,919
6.38% to 8.90% due 2003 to 2008 as of December 31, 1999
6.38% to 10.00% due 2003 to 2019 as of December 31, 1998
Medium-term notes ........................................... 150,275 177,591
8.77% to 9.23% maturing 2001 as of December 31, 1999
8.77% to 9.39% maturing 2000 to 2001 as of December 31, 1998
Notes payable ............................................... 223,451 203,116 203,438
7.50% to 9.39% due 2000 as of December 31, 1999
7.50% to 8.88% due 1999 to 2000 as of December 31, 1998
Unamortized discount and premium .............................. 16,084 17,046
------------ ------------ ------------ ------------
Total long-term borrowings .................................... 1,220,631 223,451 1,513,289 203,438
------------ ------------ ------------ ------------
Total borrowings ............................................ $ 1,220,631 $ 758,035 $ 1,513,289 $ 503,438
============ ============ ============ ============
- ------------
(1) Includes amounts due within one year of the date.
(2) At the date of the Merger, the debt was adjusted to fair market value.
Included in unamortized discount and premium is unamortized premium related
to fair value adjustments of long-term debt of approximately $17.8 million
and $33.2 million at December 31, 1999 and 1998, respectively, and is being
amortized over the respective remaining term of the related long-term debt.
123
126
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(a) Short-term Borrowings.
In 1999, Resources met its short-term financing needs primarily through a
receivables facility and the issuance of commercial paper. Resources has a $350
million revolving credit facility (Resources Credit Facility) that expires in
2003. 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 and includes a $65 million sub-facility under which
letters of credit may be obtained. As of December 31, 1999, Resources had $185
million of commercial paper outstanding having an average interest rate of
7.24%. There was no commercial paper and no loans outstanding under the
Resources Credit Facility at December 31, 1998. Letters of credit under the
sub-facility aggregated $9.3 million as of December 31, 1999.
Under a trade receivables facility (Receivables Facility) which expires in
August 2000, Resources sells, with limited recourse, an undivided interest
(limited to a maximum of $350 million as of December 31, 1999 and $300 million
as of December 31, 1998) in a designated pool of accounts receivable. The amount
of receivables sold and uncollected was $350 million and $300 million at
December 31, 1999 and December 31, 1998, respectively. The weighted average
interest rate was approximately 6.10% and 5.30% at December 31, 1999 and
December 31, 1998, respectively. 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.
(b) Long-term Debt.
Consolidated maturities of long-term debt and sinking fund requirements for
Resources are approximately $230 million in 2000, $157 million in 2001, $7
million in 2002, $507 million in 2003 and $7 million in 2004.
At December 31, 1999, Resources Corp. had issued and outstanding $92.7
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
Reliant Energy common stock and $14.24 in cash. During 1999, Resources purchased
$12.0 million aggregate principal amount of its Subordinated Debentures.
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 1999
and 1998 sinking fund requirements by delivering Subordinated Debentures
previously purchased.
In November 1998, Resources Corp. issued $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 commencing
in November 2003 if it chooses to exercise the option. The TERM Notes are
unsecured obligations of Resources Corp. 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 by the
investment bank, 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 Corp., 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 Corp. If the TERM Notes are remarketed, the final maturity
date of the TERM Notes will be November 1, 2013, subject to
124
127
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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.
For the year ended December 31, 1999, and 1998, Resources capitalized
interest of $1.9 million and $1.6 million, respectively. There was no
capitalized interest in 1997.
During the year ended December 31, 1997, Resources recorded an after-tax
extraordinary gain of $237 thousand from the extinguishment of debt.
(c) Restrictions on Debt.
The Resources Credit Facility contains covenants and requirements which
must be met to borrow funds. Such covenants are not anticipated to materially
restrict Resources from borrowing funds under such facilities.
(5) TRUST PREFERRED SECURITIES
In June 1996, a Delaware statutory business trust established by Resources
Corp. (Resources Trust) issued $172.5 million of convertible preferred
securities to the public. 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 Resources Trust used the proceeds to purchase $172.5 million of 6.25%
convertible junior subordinated debentures from Resources Corp. having an
interest rate and a maturity date that correspond to the distribution rate and
the mandatory redemption date of the convertible preferred securities. Resources
Corp. accounts for Resources Trust as a wholly owned consolidated subsidiary.
The convertible junior subordinated debentures represent Resources Trust's
sole assets and its entire operations. Resources Corp. has fully and
unconditionally guaranteed, on a subordinated basis, all of Resources Trust's
obligations with respect to the convertible preferred securities. The
convertible preferred securities are mandatorily redeemable upon the repayment
of the convertible 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 1999 and 1998, convertible preferred securities aggregating
$0.2 million and $15.5 million, respectively, were converted, leaving $0.7
million and $0.9 million liquidation amount of convertible preferred securities
outstanding at December 31, 1999 and 1998, respectively. Subject to certain
limitations, Resources Corp. has the option of deferring payments of interest on
the convertible junior subordinated debentures. During any deferral or event of
default, Resource Corp. may not pay dividends to Reliant Energy. As of December
31, 1999, no interest payments on the debentures had been deferred.
(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
related to these incentive compensation plans was $1.4 million. 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.
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.
125
128
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
WEIGHTED-AVERAGE
NUMBER EXERCISE PRICE
OF SHARES PER SHARE
---------- ----------------
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 ............ --
----------
(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 Reliant Energy stock options. There were 828,297
Resources stock options converted into 622,504 Reliant Energy stock options
at the acquisition date.
Resources applies the rules contained in Accounting Principles Opinion No.
25, "Accounting for Stock Issued to Employees." Had compensation cost been
determined in accordance with the provisions of SFAS No. 123 "Accounting for
Stock-Based Compensation," based on the "fair value methodology," the impact on
Resources' earnings for 1997 would have been immaterial.
(b) Pension.
Prior to 1999, Resources had two noncontributory retirement plans which
covered substantially all employees: (1) the plan which covers Resources'
employees other than Reliant Energy Minnegasco employees and (2) the plan which
covers Reliant Energy Minnegasco employees. These plans provided retirement
benefits based on years of service and compensation. Effective January 1, 1999,
the two noncontributory retirement plans were merged into Reliant Energy's
noncontributory retirement plan. Resources' and Reliant Energy's funding policy
is to review amounts annually in accordance with applicable regulations in order
to achieve adequate funding of projected benefit obligations. The assets of the
plan consist principally of common stocks and high-quality, interest-bearing
obligations. The net periodic pension costs (benefits) and prepaid pension costs
and benefit obligation have been determined separately for each plan prior to
the plans being merged. Subsequent to the plans being merged into Reliant
Energy's plan, the net periodic pension costs (benefits), prepaid pension costs
and benefit obligation were determined based on the employees of Resources and
their respective compensation levels.
Net pension cost for Resources includes the following components:
FORMER
CURRENT RESOURCES RESOURCES
--------------------------------------------------- -----------
TWELVE MONTHS TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, DECEMBER 31, JULY 31,
1999 1998 1997 1997
------------- ------------- ------------ ------------
(THOUSANDS OF DOLLARS)
Service cost - benefits earned during the period .... $ 15,031 $ 13,466 $ 5,095 $ 7,220
Interest cost on projected benefit obligation ....... 35,184 33,357 15,015 20,313
Expected return on plan assets ...................... (61,243) (53,043) (23,856) (26,716)
Amortization(1) ..................................... (2,026) 66
---------- ---------- ---------- ----------
Net pension cost (benefit) .......................... $ (13,054) $ (6,220) $ (3,746) $ 883
========== ========== ========== ==========
- ----------
(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).
126
129
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 benefit
obligation, plan assets and funded status for 1999 and 1998 are set forth below:
YEAR ENDED DECEMBER 31,
------------------------------
1999 1998
---------- ----------
(THOUSANDS OF DOLLARS)
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of period ............ $ 553,210 $ 513,247
Service cost ....................................... 15,031 13,466
Interest cost ...................................... 35,184 33,357
Benefits paid ...................................... (35,306) (23,870)
Plan amendments .................................... (53,736)
Actuarial (gain) loss .............................. (121,162) 70,746
---------- ----------
Benefit obligation, end of period .................. $ 446,957 $ 553,210
========== ==========
CHANGE IN PLAN ASSETS
Plan asset, beginning of period .................... $ 624,362 $ 569,718
Benefits paid ...................................... (35,306) (23,870)
Actual investment return ........................... 30,911 78,514
---------- ----------
Plan assets, end of period ......................... $ 619,967 $ 624,362
========== ==========
RECONCILIATION OF FUNDED STATUS
Funded status ...................................... $ 173,010 $ 71,152
Unrecognized prior service cost .................... (48,459) (53,736)
Unrecognized actuarial (gain) loss ................. (13,925) 84,618
---------- ----------
Net amount recognized at end of year ............... $ 110,626 $ 102,034
========== ==========
ACTUARIAL ASSUMPTIONS
Discount rate ...................................... 7.5% 6.5%
Rate of increase in compensation levels ............ 3.5 - 5.5% 3.5 -5.5%
Expected long-term rate of return on assets ........ 10.0% 10.0%
In 1998, Reliant Energy's and Resources Corp.'s respective board of
directors approved the amendment and restatement of the retirement plan,
effective January 1, 1999, which converted the present value of the accrued
benefits under their 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 for 1999 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 energy services industry as well as with other companies within the United
States. Resources will continue to reflect the costs of the pension plan
according to the provisions of SFAS No. 87, "Employers' Accounting for Pensions"
as amended. As a result of the January 1, 1999 amendment and restatement, which
is reflected in the December 31, 1998 disclosure, Resources' benefit obligation
declined $54 million.
The actuarial gains and losses are due to changes in certain actuarial
assumptions.
Prior to 1999, in addition to the noncontributory plans, Resources
maintained certain non-qualified plans which allowed participants to retain the
benefits to which they would have been entitled under its noncontributory plans
except for the federally mandated limits on such benefits or on the level of
salary on which such benefits may be calculated. Effective January 1, 1999,
these non-qualified plans were merged into a similar plan of Reliant Energy. As
of December 31, 1999, Resources had recorded a prepaid benefit obligation of
$0.6 million related to these plans.
127
130
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
As of December 31, 1998, a benefit obligation of $8.2 million was recorded
related to these plans. Expense of approximately $1 million associated with
these non-qualified plans was recorded each year during 1999, 1998 and 1997,
respectively.
(c) Savings Plan.
Prior to April 1, 1999, Resources had an employee savings plan which
covered substantially all employees other than Reliant Energy Minnegasco
employees. Under the terms of the Resources savings plan beginning January 1,
1999, employees could contribute up to 16% of total compensation, which
contributions up to 6% were matched by Resources. During 1998 and 1997,
employees could contribute up to 12% of total compensation, which contributions
up to 6% were matched by Resources. Prior to April 1, 1999, the Reliant Energy
Minnegasco employees were covered by a savings plan, the terms of which were
somewhat similar to the Resources savings plan. Effective April 1, 1999, the
Resources savings plan and the Reliant Energy Minnegasco savings plan were
merged into Reliant Energy's savings plan.
Reliant Energy's employee savings plan qualifies as cash or deferred
arrangements under Section 401(k) of the Internal Revenue Code of 1986, as
amended (IRC). Under Reliant Energy's plan, participating employees may
contribute a portion of their compensation, pre-tax or after-tax, up to a
maximum of 16% of compensation. In 1999, the savings plan was amended so that
Reliant Energy now matches 75% to 125% of the first 6% of each employee's
compensation contributed, subject to a vesting schedule, based on certain
performance goals achieved by Reliant Energy and its subsidiaries. Substantially
all of Reliant Energy's match is invested in Reliant Energy common stock.
Reliant Energy allocates to Resources the savings benefit expense related to the
employees of Resources.
Savings plan benefit expense related to Resources was $9.5 million, $10.8
million and $10.8 million in 1999, 1998 and 1997, respectively. Savings plan
expense related to Resources from the Merger date through December 31, 1997 was
$3.7 million.
(d) Postretirement Benefits.
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."
The net postretirement benefit cost includes the following components:
FORMER
CURRENT RESOURCES RESOURCES
--------------------------------------------------- -----------
TWELVE MONTHS TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, DECEMBER 31, JULY 31,
1999 1998 1997 1997
------------- ------------ ------------ ------------
(THOUSANDS OF DOLLARS)
Service cost - benefits earned during the period ...... $ 2,004 $ 635 $ 115 $ 164
Interest cost on projected benefit obligation ......... 9,060 6,660 3,561 4,948
Expected return on plan assets ........................ (583) (463) (73) (107)
Net amortization ...................................... 2,100 3,875
----------- ---------- ---------- ----------
Net postretirement benefit cost ....................... $ 12,581 $ 6,832 $ 3,603 $ 8,880
=========== ========== ========== ==========
128
131
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
postretirement benefit plans benefit obligation, plan assets and funded status
for 1999 and 1998 are set forth below:
TWELVE MONTHS ENDED DECEMBER 31,
------------------------------------
1999 1998
----------- ----------
(THOUSANDS OF DOLLARS)
CHANGE IN BENEFIT OBLIGATION
Benefit obligation, beginning of period ....... $ 144,069 $ 118,472
Service cost .................................. 2,004 635
Interest cost ................................. 9,060 6,660
Benefits paid ................................. (8,469) (11,569)
Participant contributions ..................... 1,996 1,856
Plan amendments ............................... 28,936
Actuarial gain ................................ (32,288) (921)
--------- ---------
Benefit obligation, end of period ............. $ 116,372 $ 144,069
========= =========
CHANGE IN PLAN ASSETS
Plan asset, beginning of period ............... $ 6,461 $ 4,502
Benefits paid ................................. (8,469) (11,569)
Employer contributions ........................ 8,871 11,163
Participant contributions ..................... 1,996 1,856
Actual investment return ...................... 328 509
--------- ---------
Plan assets, end of period .................... $ 9,187 $ 6,461
========= =========
RECONCILIATION OF FUNDED STATUS
Funded status ................................. $(107,185) $(137,608)
Unrecognized prior service cost ............... 25,881 28,936
Unrecognized actuarial (gain) loss ............ (22,195) 1,759
--------- ---------
Net amount recognized at end of year .......... $(103,499) $(106,913)
========= =========
ACTUARIAL ASSUMPTIONS
Discount rate ................................. 7.5% 6.5%
Rate of increase in compensation levels ....... 3.5 - 5.5% 3.5 - 5.5%
Expected long-term rate of return on assets ... 10.0% 10.0%
Health care cost trend rates - Under 65 ....... 5.8% 6.0%
Health care cost trend rates - 65 and over .... 6.2% 6.7%
The assumed health care rates gradually decline to 5.4% for both medical
categories by 2001.
If the health care cost trend rate assumptions were increased by 1%, the
accumulated postretirement benefit obligation as of December 31, 1999 would be
increased by approximately 5.3%. The annual effect of the 1% increase on the
total of the service and interest costs would be an increase of approximately
4.1%. If the healthcare cost trend rate assumptions were decreased by 1%, the
accumulated postretirement benefit obligation as of December 31, 1999 would be
decreased by approximately 5.3%. The annual effect of the 1% decrease on the
total of the service and interest costs would be a decrease of 4.2%.
In 1998, Reliant Energy's and Resources Corp.'s respective 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. Resources will continue to
reflect the costs of the retiree medical plan
129
132
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
according to the provisions of SFAS No. 106 as amended. 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 actuarial gains and losses are due to changes to certain actuarial
assumptions.
(e) Postemployment Benefits.
Resources 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 $11 million in 1999. Net postemployment benefit costs were not material in
1998 and 1997.
(7) INCOME TAXES
Reliant Energy files a consolidated federal income tax return, in which
Resources is included. Prior to the acquisition date, Resources Corp. 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 $7.5
million and $8.0 million for 1999 and 1998, respectively.
The components of Resources' income tax provision are set forth below:
CURRENT RESOURCES FORMER RESOURCES
--------------------------------------------------------- ------------------
TWELVE MONTHS TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, DECEMBER 31, JULY 31,
1999 1998 1997 1997
------------------ -------------------------------------- ------------------
(THOUSANDS OF DOLLARS)
Federal
Current........................... $ 27,732 $ 30,539 $ (12,005) $ 16,339
Deferred.......................... 53,335 61,020 36,673 12,795
Investment tax credit............. (536) (609) (262) (363)
State
Current........................... 3,520 7,235 536 833
Deferred.......................... 4,720 13,645 (559) 1,794
-------------- -------------- ------------- --------------
Income tax expense.................. $ 88,771 $ 111,830 $ 24,383 $ 31,398
============== ============== ============= ==============
130
133
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:
CURRENT RESOURCES FORMER RESOURCES
---------------------------------------------------- ----------------
TWELVE MONTHS TWELVE MONTHS FIVE MONTHS SEVEN MONTHS
ENDED ENDED ENDED ENDED
DECEMBER 31, DECEMBER 31, DECEMBER 31, JULY 31,
1999 1998 1997 1997
--------------- ---------------- ------------- ----------------
(THOUSANDS OF DOLLARS)
Income before income taxes ........... $ 188,972 $ 205,654 $ 45,230 $ 77,273
Statutory rate ....................... 35% 35% 35% 35%
-------------- -------------- -------------- --------------
Income taxes at statutory rate ....... 66,140 71,979 15,831 27,046
-------------- -------------- -------------- --------------
Increase (decrease) in tax
resulting from:
State income taxes, net of
federal income tax benefit(1) ... 5,356 14,737 (9) 1,708
Investment tax credit .............. (536) (609) (262) (363)
Goodwill amortization .............. 17,746 17,971 7,242 2,430
Other, net ......................... 65 7,752 1,581 577
-------------- -------------- -------------- --------------
Total ............................ 22,631 39,851 8,552 4,352
============== ============== ============== ==============
Income taxes ......................... $ 88,771 $ 111,830 $ 24,383 $ 31,398
============== ============== ============== ==============
Effective Rate ....................... 47.0% 54.4% 53.9% 40.6%
- ----------
(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.
131
134
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, 1999 and
1998, were as follows:
DECEMBER 31,
-----------------------
1999 1998
---------- ----------
(THOUSANDS OF DOLLARS)
Deferred Tax Assets:
Employee benefit accruals .............................. $ 23,137 $ 41,244
Gas purchase contract accruals ......................... 3,395 8,116
Operating loss carryforwards ........................... 38,954 23,178
Alternative minimum tax credit carryforwards ........... 34,239 38,361
Other .................................................. 63,076 33,615
Valuation allowance .................................... (19,139) (8,591)
--------- ---------
Total deferred tax assets - net ................ 143,662 135,923
--------- ---------
Deferred Tax Liabilities:
Property, plant and equipment .......................... 547,646 522,944
Deferred gas costs ..................................... 35,756 13,237
Deferred state income taxes ............................ 68,952 70,000
Other .................................................. 24,033 27,504
--------- ---------
Total deferred tax liabilities ................. 676,387 633,685
--------- ---------
Accumulated deferred income taxes - net .... $ 532,725 $ 497,762
========= =========
At December 31, 1999, Resources had approximately $492 million of state net
operating losses available to offset future state taxable income through the
year 2019. In addition, Resources has approximately $28 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 $1.2 million
of state alternative minimum tax credits which are available to reduce future
state income taxes payable, if any, through the year 2002. The valuation
allowance reflects a net increase of $10.5 million in 1999. 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.
(8) COMMITMENTS AND CONTINGENCIES
(a) Lease Commitments.
The following table sets forth certain information concerning Resources'
obligations under non-cancelable long-term operating leases principally
consisting of rental agreements for building space and data processing equipment
and vehicles, including major work equipment (in millions):
2000......................................... $ 15
2001......................................... 14
2002......................................... 9
2003......................................... 8
2004......................................... 6
2005 and beyond.............................. 18
----------
Total........................................ $ 70
==========
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
132
135
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
operating lease. At December 31, 1999, the unamortized value of equipment
covered by the master leasing agreement was $17 million. Resources does not
expect to lease additional property under this lease agreement.
Total rental expense for all leases was $33 million, $25 million and $24
million in 1999, 1998 and 1997, respectively.
(b) Indemnity Provisions.
At December 31, 1999 and 1998, Resources had a $0.5 million and $5.8
million, respectively, accounting reserve on its Consolidated Balance Sheets 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.
(c) 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.
(d) 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. The manufactured gas was stored in separate holders.
Resources is negotiating clean-up of one such holder. 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, 1999 and 1998, Resources had accrued $18.8 million and
$15.2 million, respectively, for remediation of the Minnesota sites. At December
31, 1999, the estimated range of possible remediation costs was $10 million to
$49 million. 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.
133
136
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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.
Other Minnesota Matters. At December 31, 1999 and 1998, Resources had
recorded accruals of $1.2 million and $5.4 million, respectively (with a maximum
estimated exposure of approximately $13 million and $8 million at December 31,
1999 and 1998, respectively), for other environmental matters for which
remediation may be required.
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,
are deferred for recovery or refund in the next rate case. At December 31, 1999
and 1998, Reliant Energy Minnegasco had over recovered $13 million, including
insurance recoveries. At December 31, 1999 and 1998, Reliant Energy Minnegasco
had recorded a liability of $20.0 million and $20.6 million, respectively, to
cover the cost of future remediation. Reliant Energy Minnegasco expects that
approximately 40% of its accrual as of December 31, 1999 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. Resources
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'
financial position, 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 operations or
cash flows.
Potentially Responsible Party Notifications. From time to time Resources
has received notices from regulatory authorities or others regarding its status
as a PRP in connection with sites found to require remediation due to the
presence of environmental contaminants. Considering the information currently
known about such sites and the involvement of Resources in activities at these
sites, Resources does not believe that these matters will have a material
adverse effect on Resources' financial position, results of operations or cash
flows.
134
137
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
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
Because Resources Corp. is a wholly owned subsidiary of Reliant Energy,
Resources' determination of reportable segments considers the strategic
operating units under which Reliant Energy manages sales, allocates resources
and assesses performance 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 Reliant Energy Latin America, 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 Dutch power
generation operation (N.V. UNA), Reliant Energy's investment in Time Warner
securities and non-Resources corporate expenses.
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 Corp. account for
intersegment sales as if the sales were to third parties, that is, at current
market prices.
Reliant Energy has identified the following reportable segments: Electric
Operations, Natural Gas Distribution, Interstate Pipelines, Wholesale Energy,
Reliant Energy Europe, Reliant Energy Latin America 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-rate regulated power generation facilities, as well as the wholesale energy
marketing and natural gas gathering businesses in North America. Reliant Energy
Europe, which was formed in 1999, owns, operates and sells electric power from
generation facilities in the Netherlands and plans to participate in the
emerging wholesale energy marketing and trading industry in Europe. Corporate
includes the Reliant Energy's and Resources' unregulated retail electric and gas
services businesses, a communications business, certain real estate holdings of
Reliant Energy and corporate costs.
135
138
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:
RELIANT
NATURAL GAS INTERSTATE WHOLESALE ENERGY RECONCILING
DISTRIBUTION PIPELINES ENERGY EUROPE CORPORATE ELIMINATIONS
------------ ----------- ----------- ----------- ----------- ------------
Current Resources
As of and for the Year Ended
December 31, 1999:
Revenues from external
customers ....................... $ 1,895,358 $ 121,514 $ 7,688,960 $ 152,865 $ 881,270
Intersegment revenues ........... 1,202 153,580 260,317 73,648 $(488,747)
Depreciation and amortization ... 132,424 49,127 25,323 20,737 10,726
Operating income ................ 124,863 113,018 45,308 32,049 (32,709)
Total assets .................... 3,386,596 2,211,842 2,773,070 3,247,290 4,645,403 (1,139,450)
Equity investments in and
advances to unconsolidated
subsidiaries .................... -- -- 78,041
Expenditures for additions
to long-lived assets ............ 205,545 30,131 529,805 834,300 89,840
Current Resources
As of and for the Year Ended
December 31, 1998:
Revenues from external
customers ....................... 1,877,185 126,988 4,289,006 586,065
Intersegment revenues ........... 1,167 155,508 167,152 97,181 (421,008)
Depreciation and amortization ... 130,658 44,025 18,204 9,646
Operating income ................ 144,447 128,328 59,170 (50,243)
Total assets .................... 3,141,762 2,050,636 1,535,007 1,679,876 (915,895)
Equity investments in and
advances to unconsolidated
subsidiaries .................... 42,252
Expenditures for additions
to long-lived assets ............ 161,735 59,358 363,174 28,077
Current Resources
For the Five Months Ended
December 31, 1997:
Revenues from external
customers ....................... 920,125 49,655 1,288,357 276,817
Intersegment revenues ........... 505 58,678 76,301 34,853 (170,337)
Depreciation and amortization 52,374 19,088 2,633 5,769
Operating income ................ 56,842 31,978 912 (39,680)
Expenditures for additions
to long-lived assets ............ 61,078 16,304 14,038 1,426,323
Former Resources
For the Seven Months Ended
July 31, 1997:
Revenues from external
customers ....................... 1,340,966 86,465 1,589,032 297,128
Intersegment revenues ........... 672 100,246 88,188 35,285 (224,391)
Depreciation and amortization ... 57,120 17,230 1,629 8,922
Operating income ................ 113,607 76,730 (13,262) (22,035)
Expenditures for additions
to long-lived assets ............ 62,998 9,619 8,996 7,025
ELIMINATION
OF NON-
RESOURCES
OPERATIONS CONSOLIDATED
----------- ------------
Current Resources
As of and for the Year Ended
December 31, 1999:
Revenues from external
customers ....................... (196,422) $10,543,545
Intersegment revenues ...........
Depreciation and amortization ... (39,661) 198,676
Operating income ................ 15,154 297,683
Total assets .................... (7,911,954) 7,212,797
Equity investments in and
advances to unconsolidated
subsidiaries .................... (78,041)
Expenditures for additions
to long-lived assets ............ (1,400,861) 288,760
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 .................... (883,851) 6,607,535
Equity investments in and
advances to unconsolidated
subsidiaries .................... (42,252)
Expenditures for additions
to long-lived assets ............ (358,372) 253,972
Current Resources
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
Expenditures for additions
to long-lived assets ............ (1,424,329) 93,414
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 ............ 88,638
136
139
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
CURRENT RESOURCES FORMER RESOURCES
------------------------------------------------------------ --------------------
YEAR ENDED YEAR ENDED FIVE MONTHS ENDED SEVEN MONTHS
DECEMBER 31, 1999 DECEMBER 31, 1998 DECEMBER 31, 1997 ENDED JULY 31, 1997
----------------- ----------------- ----------------------- --------------------
(THOUSANDS OF DOLLARS)
RECONCILIATION OF OPERATING INCOME TO
NET INCOME:
Operating income ....................... $ 297,683 $ 310,305 $ 90,756 $ 155,040
Interest expense ....................... (119,492) (111,337) (47,490) (78,660)
Distribution on trust preferred
securities .......................... (357) (632) (279) (6,317)
Income taxes ........................... (88,771) (111,830) (24,383) (31,398)
Other income (expense) ................. 11,138 7,318 2,243 7,210
Extraordinary gain ..................... 237
------------ ------------ ------------ ------------
Net income ............................. $ 100,201 $ 93,824 $ 20,847 $ 46,112
============ ============ ============ ============
REVENUES BY PRODUCTS AND SERVICES:
Retail gas sales ........................... $ 2,669,393 $ 2,372,086 1,156,618 1,597,285
Wholesale energy and energy related
sales ................................... 7,808,401 4,248,181 1,271,746 1,562,842
Gas transport .............................. 157,530 167,812 66,265 112,655
Energy products and services ............... 104,643 91,165 40,671 40,809
Elimination of non-Resources operations .... (196,422) (120,832) (9,118)
------------ ------------ ------------ ------------
Total ...................................... $ 10,543,545 $ 6,758,412 $ 2,526,182 $ 3,313,591
============ ============ ============ ============
REVENUES AND LONG-LIVED ASSETS BY
GEOGRAPHIC AREAS:
REVENUES:
US ......................................... $ 10,470,420 $ 6,879,244 $ 2,534,954 $ 3,313,591
Netherlands ................................ 152,865
Other ...................................... 116,682
Eliminations of non-Resources operations ... (196,422) (120,832) (8,772)
------------ ------------ ------------ ------------
Total ...................................... $ 10,543,545 $ 6,758,412 $ 2,526,182 $ 3,313,591
============ ============ ============ ============
LONG-LIVED ASSETS:
US ......................................... $ 6,050,501 $ 6,517,706
Netherlands ................................ 3,186,146
Other ...................................... 102 110
Eliminations of non-Resources operations ... (3,834,078) (1,409,200)
------------ ------------
Total ...................................... $ 5,402,671 $ 5,108,616
============ ============
137
140
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
DECEMBER 31,
------------------------------------------------------------------
1999 1998
------------------------------------------------------------------
CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE
-------------- ------------- ------------- ---------------
(THOUSANDS OF DOLLARS)
Financial assets of Resources:
Energy derivatives - non-trading........... $ 2,823
Financial liabilities of Resources:
Long-term debt............................. $1,444,082 $1,426,223 $1,716,727 $1,746,641
Trust preferred securities................. 967 1,030 1,157 1,467
Energy derivatives - non-trading........... 1,105 8,166
The fair values of cash and cash equivalents, marketable equity securities
and notes payable are estimated to be equivalent to carrying amounts. The
remaining fair values have been determined using quoted market prices of the
same or similar securities when available or other estimation techniques.
The fair value of financial instruments included in the trading operations
are marked-to-market at December 31, 1999 and 1998 (see Note 2). Therefore, they
are stated at fair value and are excluded from the table above.
(11) UNAUDITED QUARTERLY INFORMATION
The following unaudited quarterly financial information includes, in the
opinion of management, all adjustments (which comprise only normal recurring
accruals) necessary for a fair presentation. Quarterly results are not
necessarily indicative of a full year's operations because of seasonality and
other factors, including rate increases and variations in operating expense
patterns.
YEAR ENDED DECEMBER 31, 1999
-------------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
------------------------------ -------------- ---------------
(THOUSANDS OF DOLLARS)
Operating revenues...................................$ 1,828,064 $ 2,430,890 $ 3,446,925 $ 2,837,666
Operating income..................................... 150,177 44,949 27,728 74,829
Net income (loss).................................... 70,973 5,956 (6,532) 29,804
YEAR ENDED DECEMBER 31, 1998
-------------------------------------------------------------
FIRST SECOND THIRD FOURTH
QUARTER(1) QUARTER(1) QUARTER(1) QUARTER
------------------------------ -------------- ---------------
(THOUSANDS OF DOLLARS)
Operating revenues...................................$ 1,754,541 $ 1,380,470 $ 1,927,156 $ 1,696,245
Operating income..................................... 143,494 15,734 23,653 127,424
Net income (loss).................................... 61,828 (4,873) (2,586) 39,455
- ---------------
(1) First, second and third quarter of 1998 have been restated for the change
in accounting principal to mark-to-market accounting. For further
discussion , see Note 1(q).
138
141
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(12) SUBSEQUENT EVENT (UNAUDITED).
In March 2000, Reliant Energy announced that it had retained an investment
banking firm to assist it in evaluating strategic alternatives, including
divestiture, for (i) two of its natural gas distribution divisions, Reliant
Energy Arkla and Reliant Energy Minnegasco, (ii) its Interstate Pipelines'
operations and (iii) its natural gas gathering and pipeline services operations.
139
142
INDEPENDENT AUDITORS' REPORT
Reliant Energy Resources Corp.:
We have audited the accompanying consolidated balance sheets of Reliant
Energy Resources Corp. and its subsidiaries ("Resources") as of December 31,
1999 and 1998, and the related statements of consolidated income, consolidated
stockholder's equity and comprehensive income and consolidated cash flows for
the years ended December 31, 1999 and 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)(2) for the years
ended December 31, 1999 and 1998. 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, 1999 and 1998, and the results of their
operations and their cash flows for the years ended December 31, 1999 and 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
March 1, 2000
140
143
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE RELIANT ENERGY AND RESOURCES
CORP.
(a) Reliant Energy.
The information called for by Item 10, to the extent not set forth under
Item 1 "Business --Executive Officers of Reliant Energy," is or will be set
forth in the definitive proxy statement relating to Reliant Energy's 2000 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 Corp.
The information called for by Item 10 with respect to Resources Corp. 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) Reliant Energy.
The information called for by Item 11 is or will be set forth in the
definitive proxy statement relating to Reliant Energy's 2000 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 Corp.
The information called for by Item 11 with respect to Resources Corp. 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) Reliant Energy.
The information called for by Item 12 is or will be set forth in the
definitive proxy statement relating to Reliant Energy's 2000 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 Corp.
The information called for by Item 12 with respect to Resources Corp. is
omitted pursuant to Instruction I(2)(a) to Form 10-K (Omission of Information by
Certain Wholly Owned Subsidiaries).
141
144
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
(a) Reliant Energy.
The information called for by Item 13 is or will be set forth in the
definitive proxy statement relating to Reliant Energy's 2000 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 Corp.
The information called for by Item 13 with respect to Resources Corp. is
omitted pursuant to Instruction I(2)(a) to Form 10-K (Omission of Information by
Certain Wholly Owned Subsidiaries).
142
145
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K.
(a)(1) Reliant Energy Financial Statements.
Statements of Consolidated Income for the Three Years Ended December 31, 1999...........................58
Statements of Consolidated Comprehensive Income for the Three Years Ended December 31, 1999.............59
Consolidated Balance Sheets at December 31, 1999 and 1998...............................................60
Statements of Consolidated Cash Flows for the Three Years Ended December 31, 1999.......................61
Statements of Consolidated Stockholders' Equity for the Three Years Ended December 31, 1999.............62
Notes to Consolidated Financial Statements..............................................................63
Independent Auditors' Report - Company.................................................................105
Resources Corp. Financial Statements.
Statements of Consolidated Income for the Years Ended December 31, 1999 and 1998, the Five Months
Ended December 31, 1997 and the Seven Months Ended July 31, 1997.......................................111
Statements of Consolidated Stockholder's Equity and Comprehensive Income for the Years Ended
December 31, 1999 and 1998, the Five Months Ended December 31, 1997 and the Seven Months Ended
July 31, 1997..........................................................................................112
Consolidated Balance Sheets at December 31, 1999 and 1998..............................................113
Statements of Consolidated Cash Flows for the Years Ended December 31, 1999 and 1998, the Five Months
Ended December 31, 1997 and the Seven Months Ended July 31, 1997.....................................114
Notes to Consolidated Financial Statements.............................................................115
Independent Auditors' Reports - Resources Corp.........................................................140
(a)(2) Reliant Energy Financial Statement Schedules for the Three Years Ended December 31, 1999.
The Company: II -- Reserves............................................................................145
Resources Corp. Financial Statement Schedules for the Three Years Ended December 31, 1999.
Resources: II -- Reserves.............................................................................146
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)(3) Exhibits...............................................................................................149
See Index of Exhibits for the Company (page 149) and Resources Corp. (page 156), 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(b)(10)(iii) of Regulation S-K.
143
146
(b) Reports on Form 8-K.
The Company:
On October 18, 1999, a report on Form 8-K was filed reporting on the
Company's (1) completion of the first phase of its acquisition of the Dutch
Power Company N.V. UNA; (2) issuance of 2.0% Zero-Premium Exchangeable
Subordinated Notes due 2029 having an original principal amount of $1.0 billion;
(3) exercise of its option to convert its 11 million shares of Time Warner
convertible preferred stock into 45.8 million shares of Time Warner common
stock; and (4) preparation of an application to be filed with the Public Utility
Commission of Texas requesting a financing order authorizing the issuance by a
special purpose entity organized by the Company, pursuant to the Texas Electric
Choice Plan, of transition bonds relating to Reliant Energy HL&P's generation
related regulatory assets.
Resources:
There were no reports on Form 8-K filed in the fourth quarter of 1999.
144
147
RELIANT ENERGY, INCORPORATED AND SUBSIDIARIES
SCHEDULE II -- RESERVES
FOR THE THREE YEARS ENDED DECEMBER 31, 1999
(THOUSANDS OF DOLLARS)
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
--------------------------------------------- ------------- ---------- ------------ ------------- -------------
Year Ended December 31, 1999:
Accumulated provisions deducted from
related assets on balance sheet:
Uncollectible accounts ................. $17,566 $16,296 $ 187 $12,575 $21,474
Deferred tax assets valuation .......... 8,591 10,548 -- -- 19,139
Reserves other than those deducted from
assets on balance sheet:
Property insurance ..................... (4,953) 2,187 -- 3,906 (6,672)
Injuries and damages ................... 2,497 878 -- 1,479 1,896
Non-regulated project contingencies .... 200 -- -- 200 --
Year Ended December 31, 1998:
Accumulated provisions deducted from
related assets on balance sheet:
Uncollectible accounts ................. 16,783 11,714 -- 10,931 17,566
Deferred tax assets valuation .......... 6,353 2,238 -- -- 8,591
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 16,843 5,685 16,783
Uncollectible advances ................. 33,159 -- -- 33,159 --
Deferred tax assets valuation .......... -- -- 9,300 2,947 6,353
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
- --------------
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 and deferred tax assets acquired in business combinations.
145
148
RELIANT ENERGY RESOURCES CORP. AND SUBSIDIARIES
(A WHOLLY OWNED SUBSIDIARY OF RELIANT ENERGY, INCORPORATED)
SCHEDULE II -- RESERVES
FOR THE THREE YEARS ENDED DECEMBER 31, 1999
(THOUSANDS OF DOLLARS)
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
------------------------------------------------------------ ----------- ----------- ------------- -------------
Accumulated provisions deducted from related
assets on balance sheet:
Uncollectible accounts
Year ended December 31, 1999.............. $ 17,566 $ 16,296 $ 12,575 $ 21,287
Year ended December 31, 1998.............. 16,783 11,714 10,931 17,566
Year ended December 31, 1997.............. 13,023 14,684 $ 2,383 13,307 16,783
Deferred tax assets valuation
Year ended December 31, 1999.............. 8,591 10,548 19,139
Year ended December 31, 1998.............. 6,353 2,238 8,591
Year ended December 31, 1997.............. 6,761 2,539 2,947 6,353
- --------------
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.
146
149
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, the State of Texas, on the fifteenth day of March, 2000.
RELIANT ENERGY, INCORPORATED
(Registrant)
By: /s/ R. Steve Letbetter
-------------------------
R. Steve Letbetter,
Chairman, President 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 15, 2000.
SIGNATURE TITLE
--------- -----
/s/ R. Steve Letbetter
- --------------------------------------------- Chairman, President, Chief Executive Officer and Director
(R. Steve Letbetter) (Principal Executive Officer and Director)
/s/ Stephen W. Naeve
- --------------------------------------------- Vice Chairman and Chief Financial Officer
(Stephen W. Naeve) (Principal Financial Officer)
/s/Mary P. Ricciardello
- --------------------------------------------- Senior Vice President and Comptroller
(Mary P. Ricciardello) (Principal Accounting Officer)
/s/ James A. Baker, III Director
- ---------------------------------------------
(James A. Baker, III)
/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)
/s/ Lee W. Hogan Director
- ---------------------------------------------
(Lee W. Hogan)
/s/ T. Milton Honea Director
- ---------------------------------------------
(T. Milton Honea)
/s/ Alexander F. Schilt Director
- ---------------------------------------------
(Alexander F. Schilt)
147
150
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, the State of Texas, on the fifteenth day of March, 2000.
RELIANT ENERGY RESOURCES CORP.
(Registrant)
By: /s/ R. Steve Letbetter
-------------------------
R. Steve Letbetter,
Chairman, President 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 15, 2000.
SIGNATURE TITLE
--------- -----
/s/ R. Steve Letbetter
- --------------------------------------------- Chairman, President and Chief Executive Officer
(R. Steve Letbetter) (Principal Executive Officer and Principal Financial Officer)
/s/Mary P. Ricciardello
- --------------------------------------------- Vice President and Comptroller
(Mary P. Ricciardello) (Principal Accounting Officer)
/s/ Stephen W. Naeve Sole Director
- ---------------------------------------------
(Stephen W. Naeve)
148
151
RELIANT ENERGY, INCORPORATED
RELIANT ENERGY RESOURCES CORP.
EXHIBITS TO THE COMBINED ANNUAL REPORT ON FORM 10-K
FOR FISCAL YEAR ENDED DECEMBER 31, 1999
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(b)(10)(iii) of Regulation S-K.
(A) RELIANT ENERGY, INCORPORATED
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
2(a)(1) Agreement and Plan of Merger among former HI's Form 8-K dated 1-7629 2
Houston Industries Incorporated ("HI") August 11, 1996
Houston Lighting & Power ("HL&P" or "Reliant
Energy"), HI Merger, Inc. and NorAm dated
August 11, 1996
2(a)(2) Amendment to Agreement and Plan of Merger Registration Statement on 333-11329 2(c)
among HI, HL&P, HI Merger, Inc. and NorAm Form S-4
dated August 11, 1996
2(b)(1) Share Subscription Agreement dated March Form 10-Q for the quarter 1-3187 10.2
29, 1999 among Reliant Energy Wholesale ended March 31, 1999
Holdings (Europe) Inc., Provincie Noord
Holland, Gemeente Amsterdam, N.V.
Provinciaal En Gemeenelijk Utrechts
Stroomleveringsdedrijf, Reliant Power
Generation, Inc. and UNA
2(b)(2) Share Purchase Agreement dated March 29, Form 10-Q for the quarter 1-3187 10.3
1999 among Reliant Energy Wholesale ended March 31, 1999
Holdings (Europe) Inc., Provincie Noord
Holland, Gemeente Amsterdam, N.V.
Provinciaal En Gemeenelijk Utrechts
Stroomleveringsdedrijf, Reliant Power
Generation, Inc. and UNA
+2(b)(3) Deed of Amendment dated September 2, 1999
among Reliant Energy Wholesale Holdings
(Europe) Inc., Provincie Noord Holland,
Gemeente Amsterdam, N.V. Provinciaal En
Gemeenelijk Utrechts Stroomleveringsdedrijf,
Reliant Power Generation, Inc. and UNA
+2(c) Purchase Agreement dated as of February 19,
2000 among Reliant Energy Power Generation,
Inc., Reliant Energy, Sithe Energies, Inc. and
Sithe Northeast Generating Company, Inc.
3(a) Restated Articles of Incorporation of Form 10-K for the year ended 1-3187 3(a)
Reliant Energy, restated as of September 1997 December 31, 1997
3(b) Amendment to Restated Articles of Form 10-Q for the quarter 1-3187 3(b)
Incorporation of Reliant Energy, as of May 5, ended March 31, 1999
1999
+3(c) Amended and Restated Bylaws of Reliant Energy,
as of November 1999
3(d) Statement of Resolution Establishing Series of Form 10-Q for the quarter 1-3187 3(c)
Shares designated Series C Preference Stock ended March 31, 1998
+3(e) Statement of Resolution Establishing Series of
Shares designated Series D Preference Stock
+3(f) Statement of Resolution Establishing Series of
Shares designated Series E Preference Stock
+3(g) Statement of Resolution Establishing Series of
Shares designated Series F Preference Stock
+3(h) Articles/Certificate of Correction relating to
the Statement of Resolution Establishing Series
of Shares designated Series F Preference Stock
+3(i) Statement of Resolution Establishing Series of
Shares designated Series G Preference Stock
149
152
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
4(a)(1) Mortgage and Deed of Trust, dated November 1, 1944 Form S-7 of HL&P filed on 2-59748 2(b)
between HL&P and Chase Bank of Texas, National August 25, 1977
Association (formerly, South Texas Commercial
National Bank of Houston), as Trustee as amended
and supplemented by 20 Supplemental Indentures
thereto
4(a)(2) Twenty-First through Fiftieth Supplemental HL&P's Form 10-K for the 1-3187 4(a)(2)
Indentures to Exhibit 4(a)(1) year ended December 31, 1989
4(a)(3) Fifty-First Supplemental Indenture to Exhibit HL&P's Form 10-Q for the 1-3187 4(a)
4(a)(1) dated as of March 25, 1991 quarter ended June 30, 1991
4(a)(4) Fifty-Second through Fifty-Fifth Supplemental HL&P's Form 10-Q for the 1-3187 4
Indentures to Exhibit 4(a)(1) each dated as quarter ended March 31, 1992
of March 1, 1992
4(a)(5) Fifty-Sixth and Fifty-Seventh Supplemental HL&P's Form 10-Q for the 1-3187 4
Indentures to Exhibit 4(a)(1) each dated as quarter ended September 30,
of October 1, 1992 1992
4(a)(6) Fifty-Eighth and Fifty-Ninth Supplemental HL&P's Form 10-Q for the 1-3187 4
Indentures to Exhibit 4(a)(1) each dated as quarter ended March 31, 1993
of March 1, 1993
4(a)(7) Sixtieth Supplemental Indenture to Exhibit HL&P's Form 10-Q for the 1-3187 4
4(a)(1) dated as of July 1, 1993 quarter ended June 30, 1993
4(a)(8) Sixty-First through Sixty-Third Supplemental HL&P's Form 10-K for the 1-3187 4(a)(8)
Indentures to Exhibit 4(a)(1) each dated as year ended December 31, 1993
of December 1, 1993
4(a)(9) Sixty-Fourth and Sixty-Fifth Supplemental HL&P's Form 10-K for the 1-3187 4(a)(9)
Indentures to Exhibit 4(a)(1) each dated as year ended December 31, 1995
of July 1, 1995
4(b)(1) Rights Agreement, dated July 11, 1990, HI's Form 8-K dated July 11, 1-7629 4(a)(1)
between the Company and Texas Commerce Bank, 1990
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, dated as HI's Form 8-K dated July 11, 1-7629 4(a)(2)
of July 11, 1990, between the Company and 1990
the Rights Agent
150
153
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
4(b)(3) Form of Amended and Restated Rights Agreement Registration Statement on 333-11329 4(b)(1)
executed on August 6, 1997, including form of Form S-4
Statement of Resolution Establishing Series of
Shares Designated Series A Preference Stock and
form of Rights Agreement
4(c) Indenture, dated as of April 1, 1991, between HI's Form 10-Q for the 1-7629 4(b)
the Company and NationsBank of Texas, quarter ended June 30, 1991
National Association, as Trustee
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% 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.
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
*10(a) Executive Benefit Plan of the Company and HI's Form 10-Q for the 1-7629 10(a)(1),
First and Second Amendments thereto quarter ended March 31, 1987 10(a)(2),
effective as of June 1, 1982, July 1, and
1984, and May 7, 1986, respectively 10(a)(3)
*10(b)(1) Executive Incentive Compensation Plan of HI's Form 10-K for the year 1-7629 10(b)
the Company effective as of January 1, ended December 31, 1991
1982
*10(b)(2) First Amendment to Exhibit 10(b)(1) HI's Form 10-Q for the 1-7629 10(a)
effective as of March 30, 1992 quarter ended March 31, 1992
*10(b)(3) Second Amendment to Exhibit 10(b)(1) HI's Form 10-K for the year 1-7629 10(b)
effective as of November 4, 1992 ended December 31, 1992
*10(b)(4) Third Amendment to Exhibit 10(b)(1) HI's Form 10-K for the year 1-7629 10(b)(4)
effective as of September 7, 1994 ended December 31, 1994
*10(b)(5) Fourth Amendment to Exhibit 10(b)(1) Form 10-K for the year 1-3187 10(b)(5)
effective as of August 6, 1997 ended December 31, 1997
*10(c)(1) Executive Incentive Compensation Plan of HI's Form 10-Q for the 1-7629 10(b)(1)
the Company effective as of January 1, quarter ended March 31, 1987
1985
*10(c)(2) First Amendment to Exhibit 10(c)(1) HI's Form 10-K for the year 1-7629 10(b)(3)
effective as of January 1, 1985 ended December 31, 1988
*10(c)(3) Second Amendment to Exhibit 10(c)(1) HI's Form 10-K for the year 1-7629 10(c)(3)
effective as of January 1, 1985 ended December 31, 1991
151
154
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
*10(c)(4) Third Amendment to Exhibit 10(c)(1) HI's Form 10-Q for the 1-7629 10(b)
effective as of March 30, 1992 quarter ended March 31, 1992
*10(c)(5) Fourth Amendment to Exhibit 10(c)(1) HI's Form 10-K for the year 1-7629 10(c)(5)
effective as of November 4, 1992 ended December 31, 1992
*10(c)(6) Fifth Amendment to Exhibit 10(c)(1) HI's Form 10-K for the year 1-7629 10(c)(6)
effective as of September 7, 1994 ended December 31, 1994
*10(c)(7) Sixth Amendment to Exhibit 10(c)(1) Form 10-K for the year 1-3187 10(c)(7)
effective as of August 6, 1997 ended December 31, 1997
*10(d) Executive Incentive Compensation Plan of HI's Form 10-Q for the 1-7629 10(b)(2)
Houston Lighting & Power Company quarter ended March 31, 1987
effective as of January 1, 1985
*10(e)(1) Executive Incentive Compensation Plan of HI's Form 10-Q for the 1-7629 10(b)
the Company effective as of January 1, quarter ended June 30, 1989
1989
*10(e)(2) First Amendment to Exhibit 10(e)(1) HI's Form 10-K for the year 1-7629 10(e)(2)
effective as of January 1, 1989 ended December 31, 1991
*10(e)(3) Second Amendment to Exhibit 10(e)(1) HI's Form 10-Q for the 1-7629 10(c)
effective as of March 30, 1992 quarter ended March 31, 1992
*10(e)(4) Third Amendment to Exhibit 10(e)(1) HI's Form 10-K for the year 1-7629 10(c)(4)
effective as of November 4, 1992 ended December 31, 1992
*10(e)(5) Fourth Amendment to Exhibit 10(e)(1) HI's Form 10-K for the year 1-7629 10(e)(5)
effective as of September 7, 1994 ended December 31, 1994
*10(f)(1) Executive Incentive Compensation Plan of HI's Form 10-K for the year 1-7629 10(b)
the Company effective as of January 1, ended December 31, 1990
1991
*10(f)(2) First Amendment to Exhibit 10(f)(1) HI's Form 10-K for the year 1-7629 10(f)(2)
effective as of January 1, 1991 ended December 31, 1991
*10(f)(3) Second Amendment to Exhibit 10(f)(1) HI's Form 10-Q for the 1-7629 10(d)
effective as of March 30, 1992 quarter ended March 31, 1992
*10(f)(4) Third Amendment to Exhibit 10(f)(1) HI's Form 10-K for the year 1-7629 10(f)(4)
effective as of November 4, 1992 ended December 31, 1992
*10(f)(5) Fourth Amendment to Exhibit 10(f)(1) HI's Form 10-K for the year 1-7629 10(f)(5)
effective as of January 1, 1993 ended December 31, 1992
*10(f)(6) Fifth Amendment to Exhibit 10(f)(1) HI's Form 10-K for the year 1-7629 10(f)(6)
effective in part, January 1, 1995, and ended December 31, 1994
in part, September 7, 1994
*10(f)(7) Sixth Amendment to Exhibit 10(f)(1) HI's Form 10-Q for the 1-7629 10(a)
effective as of August 1, 1995 quarter ended June 30, 1995
*10(f)(8) Seventh Amendment to Exhibit 10(f)(1) HI's Form 10-Q for the 1-7629 10(a)
effective as of January 1, 1996 quarter ended June 30, 1996
*10(f)(9) Eighth Amendment to Exhibit 10(f)(1) HI's Form 10-Q for the 1-7629 10(a)
effective as of January 1, 1997 quarter ended June 30, 1997
*10(f)(10) Ninth Amendment to Exhibit 10(f)(1) Form 10-K for the year 1-3187 10(f)(10)
effective in part, January 1, 1997, and ended December 31, 1997
in part, January 1, 1998
*10(g) Benefit Restoration Plan of the Company, HI's Form 10-Q for the 1-7629 10(c)
effective as of June 1, 1985 quarter ended March 31, 1987
*10(h) Benefit Restoration Plan of the Company HI's Form 10-K for the year 1-7629 10(g)(2)
as amended and restated effective as of ended December 31, 1991
January 1, 1988
*10(i)(1) Benefit Restoration Plan of the Company, HI's Form 10-K for the year 1-7629 10(g)(3)
as amended and restated effective as of ended December 31, 1991
July 1, 1991
152
155
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
*10(i)(2) First Amendment to Exhibit 10(i)(1) Form 10-K for the year 1-3187 10(i)(2)
effective in part, August 6, 1997, in ended December 31, 1997
part, September 3, 1997, and in part,
October 1, 1997
*10(j)(1) Deferred Compensation Plan of the Company HI's Form 10-Q for the 1-7629 10(d)
effective as of September 1, 1985 quarter ended March 31, 1987
*10(j)(2) First Amendment to Exhibit 10(j)(1) HI's Form 10-K for the year 1-7629 10(d)(2)
effective as of September 1, 1985 ended December 31, 1990
*10(j)(3) Second Amendment to Exhibit 10(j)(1) HI's Form 10-Q for the 1-7629 10(e)
effective as of March 30, 1992 quarter ended March 31, 1992
*10(j)(4) Third Amendment to Exhibit 10(j)(1) HI's Form 10-K for the year 1-7629 10(h)(4)
effective as of June 2, 1993 ended December 31, 1993
*10(j)(5) Fourth Amendment to Exhibit 10(j)(1) HI's Form 10-K for the year 1-7629 10(h)(5)
effective as of September 7, 1994 ended December 31, 1994
*10(j)(6) Fifth Amendment to Exhibit 10(j)(1) HI's Form 10-Q for the 1-7629 10(d)
effective as of August 1, 1995 quarter ended June 30, 1995
*10(j)(7) Sixth Amendment to Exhibit 10(j)(1) HI's Form 10-Q for the 1-7629 10(b)
effective as of December 1, 1995 quarter ended June 30, 1995
*10(j)(8) Seventh Amendment to Exhibit 10(j)(1) HI's Form 10-Q for the 1-7629 10(b)
effective as of January 1, 1997 quarter ended June 30, 1997
*10(j)(9) Eighth Amendment to Exhibit 10(j)(1) Form 10-K for the year 1-3187 10(j)(9)
effective as of September 1, 1997 ended December 31, 1997
*10(j)(10) Ninth Amendment to Exhibit 10(j)(1) Form 10-K for the year 1-3187 10(j)(10)
effective as of September 3, 1997 ended December 31, 1997
*10(k)(1) Deferred Compensation Plan of the Company HI's Form 10-Q for the 1-7629 10(a)
effective as of January 1, 1989 quarter ended June 30, 1989
*10(k)(2) First Amendment to Exhibit 10(k)(1) HI's Form 10-K for the year 1-7629 10(e)(3)
effective as of January 1, 1989 ended December 31, 1989
*10(k)(3) Second Amendment to Exhibit 10(k)(1) HI's Form 10-Q for the 1-7629 10(f)
effective as of March 30, 1992 quarter ended March 31, 1992
*10(k)(4) Third Amendment to Exhibit 10(k)(1) HI's Form 10-K for the year 1-7629 10(i)(4)
effective as of June 2, 1993 ended December 31, 1993
*10(k)(5) Fourth Amendment to Exhibit 10(k)(1) HI's Form 10-K for the year 1-7629 10(i)(5)
effective as of September 7, 1994 ended December 31, 1994
*10(k)(6) Fifth Amendment to Exhibit 10(k)(1) HI's Form 10-Q for the 1-7629 10(c)
effective as of August 1, 1995 quarter ended June 30, 1995
*10(k)(7) Sixth Amendment to Exhibit 10(k)(1) HI's Form 10-Q for the 1-7629 10(c)
effective December 1, 1995 quarter ended June 30, 1995
*10(k)(8) Seventh Amendment to Exhibit 10(k)(1) HI's Form 10-Q for the 1-7629 10(c)
effective as of January 1, 1997 quarter ended June 30, 1997
*10(k)(9) Eighth Amendment to Exhibit 10(k)(1) Form 10-K for the year 1-3187 10(k)(9)
effective in part October 1, 1997 and in ended December 31, 1997
part January 1, 1998
*10(k)(10) Ninth Amendment to Exhibit 10(k)(1) Form 10-K for the year 1-3187 10(k)(10)
effective as of September 3, 1997 ended December 31, 1997
*10(l)(1) Deferred Compensation Plan of the Company HI's Form 10-K for the year 1-7629 10(d)(3)
effective as of January 1, 1991 ended December 31, 1990
*10(l)(2) First Amendment to Exhibit 10(l)(1) HI's Form 10-K for the year 1-7629 10(j)(2)
effective as of January 1, 1991 ended December 31, 1991
*10(l)(3) Second Amendment to Exhibit 10(l)(1) HI's Form 10-Q for the 1-7629 10(g)
effective as of March 30, 1992 quarter ended March 31, 1992
153
156
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
*10(l)(4) Third Amendment to Exhibit 10(l)(1) HI's Form 10-K for the year 1-7629 10(j)(4)
effective as of June 2, 1993 ended December 31, 1993
*10(l)(5) Fourth Amendment to Exhibit 10(l)(1) HI's Form 10-K for the year 1-7629 10(j)(5)
effective as of December 1, 1993 ended December 31, 1993
*10(l)(6) Fifth Amendment to Exhibit 10(l)(1) HI's Form 10-K for the year 1-7629 10(j)(6)
effective as of September 7, 1994 ended December 31, 1994
*10(l)(7) Sixth Amendment to Exhibit 10(l)(1) HI's Form 10-Q for the 1-7629 10(b)
effective as of August 1, 1995 quarter ended June 30, 1995
*10(l)(8) Seventh Amendment to Exhibit 10(l)(1) HI's Form 10-Q for the 1-7629 10(d)
effective as of December 1, 1995 quarter ended June 30, 1996
*10(l)(9) Eighth Amendment to Exhibit 10(l)(1) HI's Form 10-Q for the 1-7629 10(d)
effective as of January 1, 1997 quarter ended June 30, 1997
*10(l)(10) Ninth Amendment to Exhibit 10(l)(1) Form 10-K for the year 1-3187 10(l)(10)
effective in part August 6, 1997, in part ended December 31, 1997
October 1, 1997, and in part January 1,
1998
*10(l)(11) Tenth Amendment to Exhibit 10(l)(1) Form 10-K for the year 1-3187 10(i)(11)
effective as of September 3, 1997 ended December 31, 1997
*10(m)(1) Long-Term Incentive Compensation Plan of HI's Form 10-Q for the 1-7629 10(c)
the Company effective as of January 1, quarter ended June 30, 1989
1989
*10(m)(2) First Amendment to Exhibit 10(m)(1) HI's Form 10-K for the year 1-7629 10(f)(2)
effective as of January 1, 1990 ended December 31, 1989
*10(m)(3) Second Amendment to Exhibit 10(m)(1) HI's Form 10-K for the year 1-7629 10(k)(3)
effective as of December 22, 1992 ended December 31, 1992
*10(m)(4) Third Amendment to Exhibit 10(m)(1) HI's Form 10-K for the year 1-3187 10(m)(4)
effective as of August 6, 1997 ended December 31, 1997
*10(n) Form of stock option agreement for HI's Form 10-Q for the 1-7629 10(h)
nonqualified stock options granted under quarter ended March 31, 1992
the Company's 1989 Long-Term Incentive
Compensation Plan
*10(o) Forms of restricted stock agreement for HI's Form 10-Q for the 1-7629 10(i)
restricted stock granted under the quarter ended March 31, 1992
Company's 1989 Long-Term Incentive
Compensation Plan
*10(p)(1) 1994 Long-Term Incentive Compensation HI's Form 10-K for the year 1-7629 10(n)(1)
Plan of the Company effective as of ended December 31, 1993
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 granted under ended December 31, 1993
the Company's 1994 Long-Term Incentive
Compensation Plan
*10(p)(3) First Amendment to Exhibit 10(p)(1) HI's Form 10-Q for the 1-7629 10(e)
effective as of May 9, 1997 quarter ended June 30, 1997
*10(p)(4) Second Amendment to Exhibit 10(p)(1) Form 10-K for the year 1-3187 10(p)(4)
effective as of August 6, 1997 ended December 31, 1997
*10(p)(5) Third Amendment to Exhibit 10(p)(1) Form 10-K for the year 1-3187 10(p)(5)
effective as of January 1, 1998 ended December 31, 1998
*10(q)(1) Savings Restoration Plan of the Company HI's Form 10-K for the year 1-7629 10(f)
effective as of January 1, 1991 ended December 31, 1990
*10(q)(2) First Amendment to Exhibit 10(q)(1) HI's Form 10-K for the year 1-7629 10(l)(2)
effective as of January 1, 1992 ended December 31, 1991
*10(q)(3) Second Amendment to Exhibit 10(q)(1) Form 10-K for the year 1-3187 10(q)(3)
effective in part, August 6, 1997, and in ended December 31, 1997
part, October 1, 1997
154
157
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
*10(r)(1) Director Benefits Plan, effective as of HI's Form 10-K for the year 1-7629 10(m)
January 1, 1992 ended December 31, 1991
*10(r)(2) First Amendment to Exhibit 10(r)(1) Form 10-K for the year 1-7629 10(m)(1)
effective as of August 6, 1997 ended December 31, 1998
*10(s)(1) Executive Life Insurance Plan of the HI's Form 10-K for the year 1-7629 10(q)
Company effective as of January 1, 1994 ended December 31, 1993
*10(s)(2) First Amendment to Exhibit 10(s)(1) HI's Form 10-Q for the 1-7629 10
effective as of January 1, 1994 quarter ended June 30, 1995
*10(s)(3) Second Amendment to Exhibit 10(s)(1) Form 10-K for the year 1-3187 10(s)(3)
effective as of August 6, 1997 ended December 31, 1997
*10(t) Employment and Supplemental Benefits HI's Form 10-Q for the 1-7629 10(f)
Agreement between HL&P and Hugh Rice Kelly quarter ended March 31, 1987
*10(u)(1) Houston Industries Incorporated Savings Company's Form 10-K for the 1-7629 10(s)(4)
Trust between the Company and The year ended December 31, 1995
Northern Trust Company, as Trustee (as
amended and restated effective April 1, 1999)
10(u)(2) Note Purchase Agreement between the HI's Form 10-K for the year 1-7629 10(j)(3)
Company and the ESOP Trustee, dated as of ended December 31, 1990
October 5, 1990
+10(u)(3) Reliant Energy, Incorporated Master
Retirement Trust (as amended and restated
effective January 1, 1999 and renamed
effective May 5, 1999)
10(v)(1) Stockholder's Agreement dated as of July Schedule 13-D dated July 6, 5-19351 2
6, 1995 between the Company and Time 1995
Warner Inc.
10(v)(2) Registration Rights Agreement dated as of Schedule 13-D dated July 6, 5-19351 3
July 6, 1995 between the Company and Time 1995
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 Relative 1995
Participating, Optional or Other Special
Rights, and Qualifications, Limitations
or Restrictions Thereof of Series D
Convertible Preferred Stock of Time
Warner Inc.
*10(w)(1) Houston Industries Incorporated Executive Form 10-K for the
Deferred Compensation Trust, effective year ended December 31, 1995 1-7629 10(7)
as of December 19, 1995
*10(w)(2) First Amendment to Exhibit 10(w)(1) Form 10-Q for the quarter 1-3187 10
effective as of August 6, 1997 ended June 30, 1998
*10(x) Supplemental Pension Agreement, dated Registration Statement on 333-11329 10(aa)
July 17, 1996, between the Company and Form S-4
Lee W. Hogan
*10(y) Consulting Agreement, dated January 14, HI's Form 10-K for the year 1-7629 10(bb)
1997, between the Company and Milton ended December 31, 1996
Carroll
*10(z)(1) Employment Agreement, dated February 25, HI's Form 10-K for the year 1-7629 10(cc)
1997, between the Company and Don D. ended December 31, 1996
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 of the Form 10-K for the year 1-3187 10(aa)(1)
Company and Summary Plan Description ended December 31, 1997
effective as of September 3, 1997
*10(aa)(2) Form of Severance Agreements between the Form 10-K for the year 1-3187 10(aa)(2)
Company and each of the following ended December 31, 1997
executive officers: Lee W. Hogan, Hugh
Rice Kelly, R. Steve Letbetter, and
Stephen W. Naeve
155
158
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
*10(aa)(3) Form of Severance Agreements, between the Form 10-K for the year 1-3187 10(aa)(3)
Company and each of the following ended December 31, 1998
executive officers: David M. McClanahan,
Charles M. Oglesby, Joe Bob Perkins, and
Mary P. Ricciardello
+*10(aa)(4) Separation Agreement between Reliant Energy
and Don D. Jordan, effective December 1, 1999
*10(bb)(1) Employment Agreement, dated as of Form 10-K for the year 1-3187 10(bb)(1)
February 16, 1998, between Reliant Energy ended December 31, 1998
and Charles M. Oglesby, and Waiver and
Release pertaining thereto
*10(bb)(2) Employment Agreement, effective as of June Form 8-K for the quarter 1-3187 10(bb)(2)
1, 1999, between Reliant Energy and Don D. ended March 31, 1999
Jordan
+*10(bb)(3) Employment Agreement effective January 1, 1999
between Reliant Energy and Wayne D. Stinnett
+*10(bb)(4) Employment Agreement effective January 1, 1999
between Reliant Energy and Rollie G. Bohall
+*10(cc)(1) Reliant Energy Incorporated Savings Plan
(as amended and restated effective April 1,
1999)
+*10(cc)(2) Sixth Amendment to Exhibit 10(cc)(1)
effective as of April 1, 1999
+*10(cc)(3) Seventh Amendment to Exhibit 10(cc)(1)
dated April 29, 1999
+*10(dd) Reliant Energy, Incorporated Business Unit
Performance Share Plan effective as of
January 6, 1999
+12 Computation of Ratios of Earnings to
Fixed Charges
+21 Subsidiaries of Reliant Energy
+23 Consent of Deloitte & Touche LLP
+27 Financial Data Schedule
99(a) Letter, dated February 2, 1999, from Form 10-K for the year 1-3187
Secretary of State of the State of Texas ended December 31, 1998
regarding Assumed Name filed by Houston
Industries Incorporated to conduct
business under the name Reliant Energy,
Incorporated
(B) RELIANT ENERGY RESOURCES CORP.
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
2(a)(1) Agreement and Plan of Merger among the HI's Form 8-K dated August 1-7629 2
Company, HL&P, HI Merger, Inc. and NorAm 11, 1996
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 Resources Form 10-K for the year ended 1-3187 3(a)(1)
December 31, 1997
3(a)(2) Certificate of Merger merging former Form 10-K for the year ended 1-3187 3(a)(2)
NorAm Energy Corp. with and into HI December 31, 1997
Merger, Inc. dated August 6, 1997
3(a)(3) Certificate of Amendment changing the Form 10-K for the year ended 1-3187 3(a)(3)
name to Reliant Energy Resources Corp. December 31, 1998
3(b) Bylaws of Resources Form 10-K for the year ended 1-3187 3(b)
December 31, 1997
4(a)(1) Indenture, dated as of December 1, 1986, NorAm's Form 10-K for the 1-13265 4.14
between NorAm and Citibank, N.A., as year ended December 31, 1986
Trustee
156
159
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
4(a)(2) First Supplemental Indenture to Exhibit Form 10-K for the year ended 1-3187 4(a)(2)
4(a)(1) dated as of September 30, 1988 December 31, 1997
4(a)(3) Second Supplemental Indenture to Exhibit Form 10-K for the year ended 1-3187 4(a)(3)
4(a)(1) dated as of November 15, 1989 December 31, 1997
4(a)(4) Third Supplemental Indenture to Exhibit Form 10-K for the year ended 1-3187 4(a)(4)
4(a)(1) dated as of August 6, 1997 December 31, 1997
4(b)(1) Indenture, dated as of March 31, 1987, NorAm's Registration 33-14586 4.20
between NorAm and Chase Manhattan Bank, Statement on Form S-3
N.A., as Trustee, authorizing 6%
Convertible Subordinated Debentures due
2012
4(b)(2) Supplemental Indenture to Exhibit Form 10-K for the year ended 1-3187 4(b)(2)
4(b)(1) dated as of August 6, 1997 December 31, 1997
4(c)(1) Indenture, dated as of April 15, 1990, NorAm's Registration 33-23375 4.1
between NorAm and Citibank, N.A., as Statement on Form S-3
Trustee
4(c)(2) Supplemental Indenture to Exhibit Form 10-K for the year ended 1-3187 4(c)(2)
4(c)(1) dated as of August 6, 1997 December 31, 1997
4(d)(1) Form of Indenture between NorAm and The NorAm's Registration 33-64001 4.8
Bank of New York as Trustee Statement on Form S-3
4(d)(2) Form of First Supplemental Indenture to NorAm's Form 8-K dated June 1-13265 4.01
Exhibit 4(d)(1) 10, 1996
4(d)(3) Second Supplemental Indenture to Exhibit Form 10-K for the year ended 1-3187 4(d)(3)
4(d)(1) dated as of August 6, 1997 December 31, 1997
4(e) Indenture, dated as of December 1, 1997, Registration Statement on 333-41017 4.1
between Resources and Chase Bank of Form S-3
Texas, National Association
4(f)(1) Indenture, dated as of February 1, 1998, Form 8-K dated February 5, 1-13265 4.1
between the Company and Chase Bank of 1998
Texas, National Association, as Trustee
4(f)(2) Supplemental Indenture No. 1, dated as Form 8-K dated February 5, 1-13265 4.2
of February 1, 1998, providing for the 1998
issuance of the Company's 6 1/2%
Debentures due February 1, 2008
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% of the total assets of Resources. Resources hereby
agrees to furnish a copy of any such instrument to the SEC upon request.
REPORT OR SEC FILE OR
EXHIBIT REGISTRATION REGISTRATION EXHIBIT
NUMBER DESCRIPTION STATEMENT NUMBER REFERENCE
- -------------- ----------------------------------------------- ------------------------------ ------------- ----------
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
+27 Financial Data Schedule
157