================================================================================
UNITED STATES SECURITIES AND
EXCHANGE COMMISSION
Washington, D.C. 20549
_____________________________
FORM 10-K
[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
_____________________________
Commission Exact Name of Registrant as Specified in its Charter; I.R.S. Employer
File Number Address of Principal Executive Offices; and Telephone Number Identification No.
- ---------- ------------------------------------------------------------ ------------------
1-11668 TXU Electric Company 75-1837355
Energy Plaza, 1601 Bryan Street
Dallas, TX 75201-3411
(214) 812-4600
Securities registered pursuant to Section 12(b) of the Act:
_____________________________
Name of Each Exchange on
Registrant Title of Each Class Which Registered
---------- -------------------- ------------------------
TXU Electric Company Depositary Shares, Series A, each representing 1/4 of a share New York Stock Exchange
of $7.50 Cumulative Preferred Stock, without par value
TXU Electric Company Depositary Shares, Series B, each representing 1/4 of a share New York Stock Exchange
of $7.22 Cumulative Preferred Stock, without par value
TXU Electric Capital I, a subsidiary 8.25% Trust Originated Preferred Securities New York Stock Exchange
of TXU Electric
TXU Electric Capital III, a subsidiary 8.00% Quarterly Income Preferred Securities New York Stock Exchange
of TXU Electric
Securities registered pursuant to Section 12(g) of the Act: Preferred Stock of
TXU Electric, without par value
_____________________________
Indicate by check mark whether the registrants (1) have 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
registrants were required to file such reports), and (2) have 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 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]
Aggregate market value of TXU Electric Common Stock held by non-affiliates: None
Common Stock outstanding at March 13, 2000: TXU Electric - 101,249,700 shares,
without par value
______________________________________________
DOCUMENTS INCORPORATED BY REFERENCE - None
______________________________________________
TABLE OF CONTENTS
Page
----
PART I
Item 1. BUSINESS.............................................................. 1
BUSINESS.............................................................. 1
COMPETITIVE STRATEGY.................................................. 10
ENVIRONMENTAL MATTERS................................................. 10
Item 2. PROPERTIES............................................................ 13
Item 3. LEGAL PROCEEDINGS..................................................... 13
Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS................... 13
PART II
Item 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED
STOCKHOLDER MATTERS................................................... 14
Item 6. SELECTED FINANCIAL DATA............................................... 14
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS................................................. 14
Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK............ 14
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA........................... 14
Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE.............................................. 14
PART III
Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF REGISTRANT........................ 15
Item 11. EXECUTIVE COMPENSATION................................................ 17
Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT........ 27
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS........................ 27
PART IV
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K....... 28
APPENDIX A - Financial Information
APPENDIX B - TXU Electric Exhibits for 1999 Form 10-K
i
PART I
Item 1. BUSINESS
BUSINESS
--------
TXU Electric Company (TXU Electric), formerly Texas Utilities Electric
Company, is an electric utility engaged in the generation, purchase,
transmission, distribution and sale of electric energy wholly within the State
of Texas. TXU Electric is a wholly-owned subsidiary of Texas Utilities Company
(doing business as TXU Corp.), a Texas corporation. TXU Corp. is a holding
company that, through its subsidiaries, is engaged in the generation, purchase,
transmission, distribution and sale of electricity; the gathering, processing,
transmission and distribution of natural gas; energy marketing; and
telecommunications, retail energy services, international gas operations, power
development and other businesses primarily in the United States (US), Europe and
Australia. References herein to TXU Electric include its financing subsidiaries
(see Note 6 to Financial Statements). As an integrated electric utility, TXU
Electric currently has only one reportable segment. TXU Electric possesses all
necessary franchises, licenses and certificates to enable it to conduct its
business.
TXU Electric's service area is located in the north central, eastern and
western parts of Texas, with a population estimated at 6.1 million - about one-
third of the population of Texas. Electric service is provided to approximately
2.6 million customers in 92 counties and 370 incorporated municipalities,
including Dallas, Fort Worth, Arlington, Irving, Plano, Waco, Mesquite, Grand
Prairie, Wichita Falls, Odessa, Midland, Carrollton, Tyler, Richardson and
Killeen. The area is a diversified commercial and industrial center with
substantial banking, insurance, communications, electronics, aerospace,
petrochemical and specialized steel manufacturing, and automotive and aircraft
assembly. The territory served includes major portions of the oil and gas fields
in the Permian Basin and East Texas, as well as substantial farming and ranching
sections of the State. The service territory also includes Dallas-Fort Worth
International Airport and Alliance Airport. For energy sales and operating
revenues contributed by each customer classification, see Consolidated Operating
Statistics in Appendix A to this report.
At December 31, 1999, TXU Electric had 7,868 full-time employees. Some of
these employees provide services to other subsidiaries of TXU Corp., the cost of
which is billed to those subsidiaries.
Electric Industry Restructuring -- Legislation was passed during the 1999
session of the Texas Legislature that will restructure the electric utility
industry in Texas (1999 Restructuring Legislation). Among other matters, the
legislation continues the stipulation in Docket 18490 that earnings in excess of
the earnings cap be used as mitigation to the cost of nuclear production assets
(see Note 13 to Financial Statements); authorizes competition in the retail and
generation markets for electricity beginning January 1, 2002; provides for the
recovery of generation-related and purchased power related stranded costs and
generation-related regulatory assets; requires reductions in nitrogen oxide
(NOx) and sulfur dioxide (SO2) emissions; requires a rate freeze for all retail
customers until January 1, 2002 and certain rate reductions for residential and
small commercial customers for up to five years thereafter; and sets certain
limits on capacity owned and controlled by power generation companies. Certain
provisions of the 1999 Restructuring Legislation may be subject to different
interpretation. By September 1, 2000, each electric utility must separate
from its regulated activities its customer energy services business activities
that are otherwise already widely available in the competitive market. By
January 1, 2002, each electric utility must separate ("unbundle") its business
into the following units: a power generation company, a retail electric provider
and a transmission and distribution company or separate transmission and
distribution companies. A power generation company generates electricity that is
intended to be sold at wholesale. In general, a power generation company may not
own a transmission or distribution facility and may not have a certificated
service area. A retail electric provider sells electric energy to retail
customers and may not own or operate generation assets. A transmission and
distribution (T&D) company may only own or operate facilities to transmit or
distribute electricity. On or before April 1, 2000, each electric utility must
file with the Public Utility Commission of Texas (PUC) a separation of its costs
into competitive and regulated components, proposed tariffs for its proposed T&D
utility, and in initial estimate of its generation-related stranded costs.
1
In October 1999, TXU Electric filed a petition with the PUC for a financing
order (Docket No. 21527) to securitize $1.65 billion of its generation-related
regulatory assets and other qualified costs in accordance with the 1999
Restructuring Legislation. TXU Electric would issue transition bonds
securitizing a component of future revenues. The proceeds received by TXU
Electric are to be used solely for the purposes of retiring utility debt and
equity. On March 1, 2000, the PUC rejected TXU Electric's request for
securitization of the $1.65 billion and authorized securitization of only $357
million. TXU Electric believes this ruling is inconsistent with the 1999
Restructuring Legislation and announced that it will pursue an appeal to the
Travis County, Texas District Court following the receipt of a final order
evidencing such ruling from the PUC. TXU Electric expects that any difference
between the $1.65 billion and the amount finally authorized will continue to be
deferred until securitization of generation-related assets is addressed in 2002.
TXU Electric is unable to predict the outcome of these proceedings.
On January 10, 2000, TXU Electric filed with the PUC its business separation
plan as required by the 1999 Restructuring Legislation. This plan describes how
TXU Electric proposes to separate the provision of competitive energy services
from its regulated business activities by September 1, 2000 and how it plans to
unbundle its business. Only the T&D functions will continue to be regulated. An
independent organization certified by the PUC will oversee transmission system
planning and reliability in the State of Texas. Beginning January 1, 2002,
retail electric customers in Texas will be able to select their electricity
providers.
Generation
- ----------
Generating Units -- At December 31, 1999, TXU Electric owned or leased and
operated 80 electric generating units with an aggregate net generating
capability of 21,080 megawatts (MW). (See Item 2. Properties).
In October 1999, TXU Electric announced plans to sell six of its eighteen
natural gas-fired electricity generating plants in Texas. These plants have an
aggregate generating capacity of 3,116 MW, or approximately 15% of TXU
Electric's generating capacity. Any gain on the sale of these plants will be
recorded as a regulatory liability and applied against TXU Electric's generation
assets that may become stranded costs under provisions of the 1999 Restructuring
Legislation. (See Note 3 to Financial Statements). TXU Electric plans to sell
the plants, together with all associated assets, including land, lakes, water
rights, air permits, emission allowances and fuel transportation contracts. TXU
Electric anticipates entering into a tolling agreement with the new owners to
receive the capacity and energy from these plants for a portion of the peak load
season of 2001, and purchasing any remaining requirements on the open market.
TXU Electric anticipates completion of the plant sales by the end of 2000.
Electricity Peak Load and Generation Capability -- TXU Electric's net
capability, peak load and reserve, in MW, at the time of peak were as follows
during the years indicated:
Electricity
Peak Load (a)
---------------------------------------
Increase Firm
Net Over Peak
Year Capability Amount Prior Year Load Reserve (b)
- ------ ----------- ------ ----------- ------ -----------
1999........... 22,858 (c) 21,748 1.7% 20,724 2,134
1998........... 22,579 (d) 21,383 5.1% 20,351 2,228
1997........... 22,449 (e) 20,351 3.5% 19,229 3,220
_____________
(a) The 1999 peak load occurred on August 26. TXU Electric's peak load includes
interruptible load at the time of peak of 1,024 MW in 1999, 1,032 MW in
1998 and 1,122 MW in 1997.
(b) Amount of net capability in excess of firm peak load at the time of peak.
(c) Included in net capability is 1,778 MW of firm purchased capacity.
(d) Included in net capability is 1,499 MW of firm purchased capacity.
(e) Included in net capability is 1,224 MW of firm purchased capacity.
The peak load changes for 1999 as compared to 1998, as well as the
peak load changes for 1998 as compared to 1997, resulted primarily from customer
growth and increased usage due to hotter-than-normal weather. The peak load
change for 1997, compared to the prior year, resulted primarily from customer
growth and weather factors.
2
TXU Electric expects to continue to purchase capacity in the future from various
sources. (See Fuel Supply and Purchased Power and Note 14 to Financial
Statements.) Firm peak load (excluding interruptible contracts) increases over
the next two years are expected to average approximately 2.6% annually, after
consideration of load management programs.
Resource Estimates -- Changes in utility regulation and legislation at the
federal and state levels, such as the Public Utility Regulatory Policy Act of
1978 (PURPA), the National Energy Policy Act of 1992 (Energy Policy Act) and,
most recently, the 1999 Restructuring Legislation for the electric industry in
Texas have significantly changed the way utilities plan for new resources. The
1999 Restructuring Legislation incorporates sweeping changes for electric
utilities operating in Texas by opening up the generation portion of the
business to competition. Beginning January 1, 2002, retail electric customers in
Texas will be able to select their electricity providers. Thus, each retail
electric provider will be responsible for providing generation resources to its
customers.
Because of these competitive forces TXU Electric will be purchasing some
of its energy requirements needed to serve customer loads through resource
contracts with third-party suppliers. Thus, for planning purposes, TXU Electric
can no longer readily identify the ownership and types of resources needed to
serve its customers prior to the actual selection of the resource contracts. TXU
Electric will fill some of its resource needs through load management and
renewable resources. It does not expect to have difficulty filling the remainder
of its requirements from purchased power.
TXU Electric has secured resources for the years 2000 and 2001 from
various suppliers through short-term (two years or less) purchased power
contracts. (See Fuel Supply and Purchased Power.) Additional resource needs
required for 2002 and beyond will be acquired in the competitive energy
marketplace.
Retail competition in Texas will be effective on January 1, 2002 for
customers of investor-owned electric utilities. At that time, by law, TXU
Electric must lower its retail rates charged to residential and small commercial
customers in its service area to rates that are 6% lower than the rates that
were in effect on January 1, 1999. This is known as the "price to beat," meaning
that competitors will try to beat this price to attract new customers. This rate
is frozen for residential and small commercial customers for three years, with
respect to each class of service, until 40% of the electric power consumed by
customers in that class or segment is supplied by competing Retail Electric
Providers (REPs). On January 1, 2005, TXU Electric will be able to lower its
retail rates to compete directly with other REPs, but must continue to offer the
"price to beat" through December 31, 2006. Electric retail rates will then be
driven by market forces and will no longer be regulated.
3
Fuel Supply And Purchased Power -- Net input during 1999 totaled 106,039
gigawatt hours (GWh) of which 94,575 GWh were generated by TXU Electric. Average
fuel and purchased power cost (excluding capacity charges) per kilowatt-hour
(kWh) of net input were 1.81 cents for 1999, 1.77 cents for 1998 and 1.84 cents
for 1997. A comparison of TXU Electric's resource mix for net kWh input and the
unit cost per million British thermal units (Btu) of fuel during the last three
years is as follows:
Mix for Net Unit Cost
kWh Input Per Million Btu
---------------------------- -------------------------------
1999 1998 1997 1999 1998 1997
------ ------ ------ ------ ------ -----
Fuel for Electric Generation:
Gas/Oil (a)................. 34.3% 36.7% 32.9% $2.59 $2.39 $2.80
Lignite/Coal (b)............ 38.5 36.5 38.9 1.03 1.03 1.04
Nuclear..................... 16.4 16.4 17.1 0.57 0.59 0.57
----- ----- -----
Total/Weighted Average Fuel Cost.. 89.2 89.6 88.9 $1.56 $1.52 $1.62
Purchased Power (c)............... 10.8 10.4 11.1
----- ----- -----
Total............................. 100.0% 100.0% 100.0%
===== ===== =====
_______________
(a) Fuel oil was an insignificant component of total fuel and purchased power
requirements.
(b) Lignite/coal cost per ton to TXU Electric was $13.30 in 1999, $13.47 in
1998 and $13.55 in 1997.
(c) Excludes power purchased by TXU Electric's affiliate, TXU SESCO Company,
formerly Southwestern Electric Service Company (TXU SESCO), from TXU
Electric: 1999 - 0 GWh; 1998 - 267 GWh ; and 1997 - 548 GWh . Includes TXU
Electric purchases from TXU SESCO: 1999 - 6.1 GWh; 1998 - 6.3 GWh; and
1997-5.2 GWh.
In 1999, TXU Electric purchased a net of 11,464 GWh or approximately 10.8%
of its energy requirements. TXU Electric had available 1,778 MW of firm
purchased capacity under contract. TXU Electric received energy in 1999 under
purchased power contracts for energy from wind turbines equivalent to
approximately 41 MW. The wind generation facilities include eight of the largest
commercial wind turbines in the world, rated at 1.65 MW each. TXU Electric
expects to acquire additional amounts of purchased resources in the future to
adequately and reliably accommodate its customers' electrical needs. Such
resources will be acquired in accordance with the requirements of Texas Public
Utility Regulatory Act, as amended (PURA) and the PUC Substantive Rules.
Beginning January 1, 2002, the acquisition of resources will generally not be
subject to regulation by the PUC. For information concerning future resource
requirements, see Electricity Peak Load and Generation Capability.
TXU Electric is unable to predict: (i) whether or not problems may be
encountered in the future in obtaining the fuel and purchased power it will
require, (ii) the effect upon operations of any difficulty it may experience in
protecting rights to fuel and purchased power now under contract, or (iii) the
future costs of fuel and purchased power and to what extent they will be
recoverable, see Regulation and Rates.
Gas/Oil -- Fuel gas for units at eighteen of the principal generating
stations of TXU Electric, having an aggregate net gas/oil capability of 12,955
MW, was provided during 1999 by TXU Fuel Company (TXU Fuel), an affiliate of TXU
Electric. TXU Fuel supplied approximately 12% of such fuel gas requirements
under contracts with producers at the wellhead and 88% under contracts with
commercial suppliers.
Fuel oil can be stored at seventeen of the principally gas-fueled
generating stations. At December 31, 1999, TXU Electric had fuel oil storage
capacity sufficient to accommodate approximately 6.1 million barrels of oil and
had approximately 2.3 million barrels of oil in inventory.
TXU Fuel has acquired supplies of gas from producers at the wellhead under
contracts expiring at intervals through 2008. As gas production under these
contracts declines and contracts expire, new contracts are expected to be
negotiated to replenish or augment such supplies. TXU Fuel has negotiated gas
purchase contracts, with terms ranging from one to ten years, with a number of
commercial suppliers. Additionally, TXU Fuel has entered into a number of short-
term gas purchase contracts with other commercial suppliers at spot market
prices. In general, these spot gas purchase contracts require both the buyer and
seller to purchase and deliver the gas on negotiated terms during the agreed-
upon delivery period. In the past, curtailments of gas deliveries have been
experienced during periods of winter peak gas demand; however, such curtailments
have been of relatively short duration, have had a
4
minimal impact on operations and generally have required utilization of fuel oil
and gas storage inventories to replace the gas curtailed. No curtailments were
experienced during 1999.
TXU Fuel owns and operates an intrastate natural gas pipeline system that
extends from the gas-producing area of the Permian Basin in West Texas to the
East Texas gas fields and southward to the Gulf Coast area. This system includes
a one-half undivided interest in a 36-inch pipeline that extends 391 miles from
the Permian Basin area to a point of termination south of the Dallas-Fort Worth
area. Additionally, TXU Fuel owns a 39% undivided interest in another 36-inch
pipeline connecting to this pipeline and extending 58 miles eastward to one of
TXU Fuel's underground gas storage facilities. TXU Fuel also owns and operates
approximately 1,500 miles of various smaller capacity lines that are used to
gather and transport natural gas from other gas-producing areas. The pipeline
facilities of TXU Fuel form an integrated network through which fuel gas is
gathered and transported to certain TXU Electric generating stations for use in
the generation of electric energy.
TXU Fuel also owns and operates three underground gas storage facilities
with a usable capacity of 26.9 billion cubic feet (Bcf), with approximately 14.3
Bcf of gas in inventory at December 31, 1999. Gas stored in these facilities
currently can be withdrawn for use during periods of peak demand to meet
seasonal and other fluctuations or curtailment of deliveries by gas suppliers.
Under normal operating conditions, up to 400 million cubic feet can be withdrawn
each day for a ten-day period, with withdrawals at lower rates thereafter. One
of these gas storage facilities, the Worsham-Steed facility located in Jack
County, Texas will be retired after withdrawal of the economically recoverable
gas.
Lignite/Coal -- Lignite is used as the primary fuel in two units at the
Big Brown generating station (Big Brown), three units at the Monticello
generating station (Monticello), three units at the Martin Lake generating
station (Martin Lake), and one unit at the Sandow generating station (Sandow),
having an aggregate net capability of 5,825 MW. TXU Electric's lignite units
have been constructed adjacent to surface minable lignite reserves. TXU Electric
owns in fee or has under lease an estimated 465 million tons of proven reserves
dedicated to the Big Brown, Monticello and Martin Lake generating stations. TXU
Electric also owns in fee or has under lease in excess of 229 million tons of
proven reserves not dedicated to specific generating stations. TXU Mining
Company (TXU Mining), an affiliate of TXU Electric, operates owned and/or leased
equipment to remove the overburden and recover the lignite. One of TXU
Electric's lignite units, Sandow Unit 4, is fueled from lignite deposits owned
by Alcoa, which furnishes fuel at no cost to TXU Electric for that portion of
energy generated from such unit that is equal to the amount of energy delivered
to Alcoa.
Lignite production operations at Big Brown, Monticello and Martin Lake are
accompanied by an extensive reclamation program that returns the land to
productive uses such as wildlife habitats, commercial timberland and pasture
land. For information concerning federal and state laws with respect to surface
mining, see Environmental Matters.
TXU Electric supplements its lignite fuel at Big Brown, Monticello and
Martin Lake with western coal from the Powder River Basin (PRB) in Wyoming. The
coal is purchased from three suppliers under two or three year contracts and is
transported from the PRB to TXU Electric's generating plants by railcar under
three contracts that range in length from two to seven years.
TXU Electric began supplementing its lignite fuel by utilizing western
coal at Monticello in 1996, at Martin Lake in November 1999 and at Big Brown in
January 2000. Construction of a rail spur into Big Brown to facilitate the
delivery of western coal was completed in January 2000, six months earlier than
anticipated.
Nuclear -- TXU Electric owns and operates two nuclear-fueled generating
units at the Comanche Peak nuclear powered electric generating station (Comanche
Peak), each of which is designed for a net capability of 1,150 MW.
The nuclear fuel cycle requires the mining and milling of uranium ore to
provide uranium oxide concentrate (U3O8), the conversion of U3O8 to uranium
hexafluoride (UF6), the enrichment of the UF6 and the fabrication of the
enriched uranium into fuel assemblies. TXU Electric has on hand, or has
contracted for, the raw materials and services it expects to need for its
nuclear units through future years as follows: uranium (2001), conversion
(2003),
5
enrichment (2014), and fabrication (2011). Although TXU Electric cannot predict
the future availability of uranium and nuclear fuel services, TXU Electric does
not currently expect to have difficulty obtaining U3O8 and the services
necessary for its conversion, enrichment and fabrication into nuclear fuel for
years later than those shown above.
The Nuclear Waste Policy Act of 1982, as amended (NWPA), provides for the
development by the United States Department of Energy (DOE) of interim storage
and permanent disposal facilities for spent nuclear fuel and/or high level
radioactive waste materials. In January 1998, the DOE did not meet its
obligation to begin accepting spent nuclear fuel. The DOE continues to maintain
its position that no obligation to begin acceptance of spent nuclear fuel exists
despite multiple industry initiated lawsuits challenging that position and a US
Court of Appeals decision that such obligation exists. TXU Electric is unable to
predict what impact, if any, the DOE's delay will have on TXU Electric's future
operations. Under provisions of the NWPA, funding for the program is provided by
a one-mill per kWh fee currently levied on electricity generated and sold from
nuclear reactors, including the Comanche Peak units.
TXU Electric's onsite spent nuclear fuel storage capability is sufficient
to accommodate the operation of Comanche Peak through the year 2017, while fully
maintaining the capability to off-load the core of one of the nuclear-fueled
generating units. Additional approval from the Nuclear Regulatory Commission
(NRC) will be required to utilize this full storage capability. TXU Electric is
currently pursuing options for utilizing a larger portion of the full storage
capability, subject to approval by the NRC.
Transmission
- ------------
In 1995, TXU Electric became the first utility in Texas to functionally
unbundle, or separate, its transmission operations into a business unit. The
unit operates independently within the larger company and has the flexibility to
adapt to changing market and regulatory forces. TXU Electric is a member of the
Electric Reliability Council of Texas (ERCOT), an intrastate network of
investor-owned entities, cooperatives, public entities, non-utility generators
and power marketers. ERCOT is the regional reliability coordinating organization
for member electric power systems in Texas, the Independent System Operator
(ISO) of the interconnected transmission system of those systems, and is
responsible for ensuring equal access to transmission service by all wholesale
market participants in the ERCOT region.
The function of the transmission business is to provide non-discriminatory
wholesale open access to TXU Electric's transmission facilities through business
practices consistent with the standard of conduct rules enacted by the PUC. The
transmission system transverses almost 200,000 square miles of Texas and
consists of over 13,000 circuit miles of transmission line and over 900
substations.
The transmission business supports the operation of the ERCOT ISO and all
ERCOT members, as well as TXU Electric's responsibilities and obligations to its
wholesale and retail customers. The transmission business unit has planning,
design, construction, operation and maintenance responsibility for the
transmission grid and for the load serving substations.
Services are provided under tariffs approved by the PUC and the Federal
Energy Regulatory Commission (FERC). Transmission service offers the use of the
transmission system for delivery of power over facilities operating at 60,000
volts and above. Transformation service offers the use of substation assets to
transform voltage to below 60,000 volts. Other services offered by the
transmission business include: static and dynamic scheduling and miscellaneous
services such as system impact studies, facilities studies, and maintenance of
substations and transmission lines owned by other parties.
The transmission business is participating with the ISO and other ERCOT
utilities to plan, design and obtain regulatory approval for and construct new
transmission lines necessary to increase bulk power transfer capability and to
remove existing limitations on the ERCOT transmission grid.
The principal generating facilities of TXU Electric and load centers of
TXU Electric and TXU SESCO are connected by 4,133 circuit miles of 345-kilovolt
(kV) transmission lines and 9,754 circuit miles of 138- and 69-kV
6
transmission lines. TXU SESCO, operating in the eastern and central part of
Texas, is connected to TXU Electric by three 138-kV lines, ten 69-kV lines and
three lines at distribution voltage.
TXU Electric is connected by six 345-kV lines to Reliant Energy
Company; by three 345-kV, eight 138-kV and nine 69-kV lines to West Texas
Utilities Company; by two 345-kV and eight 138-kV lines to the Lower Colorado
River Authority; by four 345-kV and eight 138-kV lines to the Texas Municipal
Power Agency; by one asynchronous High Voltage Direct Current (HVDC)
interconnection to Southwestern Electric Power Company; and at several points
with smaller systems operating wholly within Texas.
Distribution
- ------------
The TXU Electric distribution system supplies electricity to approximately
2.6 million customers (including approximately 2.3 million residential customers
and 304,000 commercial and industrial businesses). On average, TXU Electric has
added approximately 47,000 customers to its system each year for the last
several years and over 68,000 in 1999. The electric distribution business
consists of the ownership, management, construction, maintenance and operation
of the distribution network within TXU Electric's certificated service area.
TXU Electric's distribution network receives electricity from the
transmission grid through power distribution substations and distributes
electricity to end users and wholesale customers through approximately 2,800
distribution feeders.
The TXU Electric distribution network consists of approximately 52,500
miles of overhead primary conductors, 21,650 miles of overhead secondary and
street light conductors, 10,700 miles of underground primary conductors and
6,067 miles of underground secondary and street light conductors. The majority
of the distribution system operates at 25-kV and 12.5-kV.
REGULATION AND RATES
The PUC has original jurisdiction over electric rates and service in
unincorporated areas and those municipalities that have ceded original
jurisdiction to the PUC and has exclusive appellate jurisdiction to review the
rate and service orders and ordinances of municipalities. Generally, PURA
prohibits the collection of any rates or charges (including charges for fuel) by
a public utility that does not have the prior approval of the PUC.
TXU Electric is subject to the jurisdiction of the NRC with respect to
nuclear power plants. NRC regulations govern the granting of licenses for the
construction and operation of nuclear power plants and subject such plants to
continuing review and regulation.
TXU Electric is subject to various federal, state and local regulations.
(See discussion below and Environmental Matters.) TXU Electric believes that it
is not a public utility as defined in the Federal Power Act and has been advised
by its counsel that it is not subject to general regulation under such act.
Docket 9300 -- The PUC's final order (Order) in connection with TXU
Electric's January 1990 rate increase request (Docket 9300) was ultimately
reviewed by the Supreme Court of Texas. As a result, an aggregate of $909
million of disallowances with respect to TXU Electric's reacquisitions of
minority owners' interests in Comanche Peak, which had previously been recorded
as a charge to TXU Electric's earnings, has been remanded to the District Court
with instructions that it be remanded to the PUC for reconsideration on the
basis of a prudent investment standard. On remand, the PUC also was required to
reevaluate the appropriate level of TXU Electric's construction work in progress
included in rate base in light of its financial condition at the time of the
initial hearing. In connection with the settlement of Docket 18490, proceedings
in the remand of Docket 9300 have been stayed. TXU Electric cannot predict the
outcome of the reconsideration of the Order on remand by the PUC.
Docket 18490 -- The PUC approved the non-unanimous stipulation filed on
December 17, 1997 by TXU Electric, together with the General Counsel of the PUC,
the Office of Public Utility Counsel and various other parties interested in TXU
Electric's rates and services. The stipulation, modified to incorporate changes
made by the PUC,
7
resulted in base rate credits beginning January 1, 1998, of 4% for residential
customers, 2% for general service secondary customers and 1% for all other
retail customers, and additional base rate credits for residential customers of
1.4% beginning January 1, 1999. Certain parties that did not sign the
stipulation have appealed the PUC's approval by filing suit in state district
court. TXU Electric cannot predict the outcome of these appeals.
In accordance with the stipulation, from January 1, 1998 through June 30,
1999, earnings in excess of the earnings cap were recorded as additional
depreciation of nuclear production assets, and a reclassification of
depreciation expense was made from T&D to nuclear production assets. As
discussed in Notes 2 and 3 to Financial Statements, application of Statement of
Financial Accounting Standards No. 71 to the generation portion of TXU
Electric's business was discontinued as of June 30, 1999. Effective July 1,
1999, earnings in excess of the earnings cap imposed by the 1999 Restructuring
Legislation were recorded as a reduction of revenues, with a corresponding
regulatory liability recorded. Upon final PUC determination, the regulatory
liability associated with earnings in excess of the earnings cap will be applied
against TXU Electric's stranded generation assets as determined under the 1999
Restructuring Legislation's market valuation criteria or refunded to customers.
Additionally, effective July 1, 1999, TXU Electric ceased the
reclassification of T&D depreciation expense to nuclear production assets.
Instead, an amount equal to T&D depreciation expense for the period was recorded
as a regulatory asset, which will be amortized as it is recovered through the
Distribution portion of the business. An equivalent amount was recorded as a
regulatory liability which will be applied against TXU Electric's stranded
generation assets as determined under the 1999 Restructuring Legislation's
market valuation criteria or refunded to customers.
Fuel Cost Recovery Rule -- Pursuant to a PUC rule, the recovery of TXU
Electric's eligible fuel costs is provided through fixed fuel factors. The rule
allows a utility's fuel factor to be revised upward or downward every six
months, according to a specified schedule. A utility is required to petition to
make either surcharges or refunds to ratepayers, together with interest based on
a twelve-month average of prime commercial rates, for any material cumulative
under- or over-recovery of fuel costs. If the cumulative difference of the
under- or over-recovery, plus interest, exceeds 4% of the annual estimated fuel
costs most recently approved by the PUC, it will be deemed to be material.
Final reconciliation of fuel costs must be made either in a reconciliation
proceeding, which may cover no more than three years and no less than one year,
or in a general rate case. In a final reconciliation, a utility has the burden
of proving that fuel costs under review were reasonable and necessary to provide
reliable electric service, that it has properly accounted for its fuel-related
revenues, and that fuel prices charged to the utility by an affiliate were
reasonable and necessary and not higher than prices charged for similar items by
such affiliate to other affiliates or nonaffiliates. For generating utilities
like TXU Electric, through August 31, 1999, the rule provided for recovery of
purchased power capacity costs through a power cost recovery factor with respect
to purchases from qualifying facilities, to the extent such costs were not
otherwise included in base rates. Pursuant to the 1999 Restructuring
Legislation, the Power Cost Recovery Factor will be frozen between September 1,
1999 and January 1, 2002. The energy-related costs of such purchases continue to
be included in the fixed fuel factor. TXU Electric's last fuel reconciliation
proceeding (Docket 20285) covered eligible fuel and purchased power expenses
incurred during the period July 1, 1995 through June 30, 1998, amounting to a
total of $5.04 billion, of which $52 million was disallowed.
8
COMPETITION
General -- The Energy Policy Act addresses a wide range of energy
issues and is intended to increase competition in electric generation and
broaden access to electric transmission systems. In addition, PURA impacts the
PUC and its regulatory practices and encourages increased competition in the
wholesale electric utility industry in Texas, and the 1999 Restructuring
Legislation will restructure the industry and introduce competition in the Texas
retail and generation markets beginning January 1, 2002. Although TXU Electric
is unable to predict the ultimate impact of these and any other related
regulations or legislation on its operations, it believes that such actions are
consistent with the trend toward increased competition in the energy industry.
The 1999 Restructuring Legislation will restructure the electric
utility industry in Texas. Among other matters, the 1999 Restructuring
Legislation authorizes competition in the retail and generation markets for
electricity beginning January 1, 2002; provides for the recovery of generation-
related and purchased power related stranded costs and generation-related
regulatory assets; requires reductions in NOx and SO2 emissions; requires a rate
freeze for all customers until January 1, 2002 and certain rate reductions for
residential and small commercial customers for up to five years thereafter; and
sets certain limits on capacity owned and controlled by power generation
companies. Project teams have been established to prepare TXU Electric for a
competitive environment. These teams are comprised of resources from all facets
of TXU Corp.'s business. These teams continue to formulate short- and long-term
strategies to address implementation of the 1999 Restructuring Legislation.
As legislative, regulatory, economic and technological changes occur,
the energy and utility industries are faced with increasing pressure to become
more competitive while adhering to regulatory requirements. The level of
competition is affected by a number of variables, including price, reliability
of service, the cost of energy alternatives, new technologies and governmental
regulations.
As a result of the shift in emphasis toward greater competition, large
and small industry participants are offering energy services and energy-related
products that are both economically and environmentally attractive to customers.
In Texas, aggressive marketing of competitive prices by rural electric
cooperatives, municipally-owned electric systems, and other energy providers not
subject to the traditional governmental regulation experienced by the utility
industry has intensified competition within the state's wholesale markets, in
multi-certificated areas, and retail customer markets.
TXU Electric is aggressively managing its operating costs and capital
expenditures through streamlined business processes and is developing and
implementing strategies to address an increasingly competitive environment.
Furthermore, there is increasing pressure on utilities to reduce
costs, including the cost of power, and tailor energy services to the specific
needs of customers. Such competitive pressures among electric utility and non-
utility power producers could result in the loss of some retail energy services
customers. Amounts invested by TXU Electric in certain of its assets could
become stranded costs, which are investments and commitments that may not be
recoverable from customers as a result of competitive pricing. The PUC's latest
available estimate for TXU Electric's potentially stranded retail costs ranged
from a projected excess of net book value over market value of $5.8 billion to a
projected excess of market value over net book value of $3.8 billion. In
response to competitive pressures, many utilities are implementing significant
restructuring and re-engineering initiatives designed to make them more
competitive. Since the implementation by TXU Corp. of an Operations Review and
Cost Reduction program in April 1992, TXU Electric has continued to take steps
to reduce costs by streamlining business processes and operating practices. (For
information pertaining to the effects of competition on the treatment of certain
regulatory assets and liabilities, see Note 2 to Financial Statements.)
Wholesale Competition -- Federal legislation such as the PURPA and the
Energy Policy Act, as well as initiatives in various states, encourage wholesale
competition among electric utility and non-utility power producers. Together
with increasing customer demand for lower-priced electricity and other energy
services, these measures have accelerated the industry's movement toward a more
competitive pricing and cost structure.
9
Amendments to PURA made during the 1995 session of the Texas
Legislature allow for wholesale pricing flexibility. While wholesale rates for
electric utilities are not deregulated, wholesale tariffs or contracts with
charges less than approved rates but greater than the utility's marginal cost
may be approved by the regulatory authority upon application by the utility. In
the wholesale power market, TXU Electric competes with a variety of utilities
and other suppliers, some of which are willing and able to sell at rates below
TXU Electric's standard wholesale power service rate as approved by the PUC. As
directed by the 1999 Restructuring Legislation (see Note 3 to Financial
Statements), beginning in January 2002, wholesale rates will no longer be
regulated. TXU Electric is unable to predict the extent of future competitive
developments in the wholesale market or what impact, if any, such developments
may have on its operations.
Open-Access Transmission -- At the federal level, the FERC issued
Order No. 888 in April 1996, which requires all FERC-jurisdictional electric
public utilities to offer third parties wholesale transmission services under an
open-access tariff. In May 1997, TXU Electric filed with the FERC a modification
of its tariff governing service to, from and over certain HVDC interconnections
between ERCOT and the Southwest Power Pool, which, in October 1997, was accepted
by the FERC with minor modifications.
In August 1999, the Texas Court of Appeals issued a judgment declaring
invalid PUC rules governing open-access wholesale transmission service. These
rules, adopted in February 1996, guaranteed open-access wholesale transmission
service by electric utilities in ERCOT to other utilities and non-utility power
suppliers, and established a rate formula to determine access charges for the
transmission of wholesale electricity. In its decision, the court concluded that
the PUC lacks the statutory authority to establish transmission access rates,
and therefore rendered the transmission rules invalid. Several interested
parties and the PUC filed motions for rehearing with the Court of Appeals,
asking the court to reverse its decision and to recognize the PUC's authority to
set wholesale transmission rates in ERCOT. In January 2000, a judgment was
rendered on the motions for rehearing by the Texas Court of Appeals, declaring
that certain subsections of the open-access rules are invalid, while still
concluding that the PUC lacks statutory authority to establish transmission
access rates. TXU Electric is unable to predict the impact of this judgment on
open-access transmission rates at this time.
Customers -- There are no individually significant customers upon
which TXU Electric's business or results of operations are highly dependent.
COMPETITIVE STRATEGY
--------------------
As a result of the provisions of the 1999 Restructuring Legislation,
TXU Electric plans to further implement a portfolio management/merchant trading
strategy in conjunction with its upstream (generation and fuel supply) and
downstream (retail customers) positions to effectively serve its customers,
minimize risks and maximize margins available in the Texas markets. This
strategy has been effectively implemented by an affiliate in Europe and is being
implemented by another affiliate in Australia.
ENVIRONMENTAL MATTERS
---------------------
TXU Electric is subject to various federal, state and local
regulations dealing with air and water quality and related environmental
matters. (See Item 2. Properties and Management's Discussion and Analysis of
Financial Condition and Results of Operations.)
Air -- Under the Texas Clean Air Act, the Texas Natural Resource
Conservation Commission (TNRCC) has jurisdiction over the permissible level of
air contaminant emissions from generating facilities located within the State of
Texas. In addition, the new source performance standards of the Environmental
Protection Agency (EPA) promulgated under the Federal Clean Air Act, as amended
(Clean Air Act), which have also been adopted by the TNRCC, are applicable to
certain generating units. TXU Electric's generating units have been built to
operate in compliance with applicable regulations and emission standards
promulgated pursuant to these Acts; however, due
10
to variations in the quality of the lignite fuel, operation of certain of the
lignite-fueled generating units at reduced loads is necessary from time to time
in order for TXU Electric to maintain compliance with these standards at these
units. With these occasional reduced loads, TXU Electric has achieved and
continues to achieve material compliance with the Clean Air Act's emission
standards.
The Clean Air Act includes provisions which, among other things, place limits
on the SO2 emissions produced by generating units. In addition to the new source
performance standards applicable to SO2, the Clean Air Act required that fossil-
fueled plants meet certain SO2 emission allowances by 1995 (Phase I), and
requires more restrictions on SO2 emission allowances by 2000 (Phase II). TXU
Electric's generating units were not affected by the Phase I requirements. The
applicable Phase II requirements currently are met by 52 out of 56 TXU Electric
generating units to which those requirements apply. Because the SO2 emissions
from the other four units are relatively low and alternatives are available to
enable these units to reduce SO2 emissions or utilize compensatory reduction
allowances achieved at other units, material compliance with the applicable
Phase II sulfur dioxide requirements is not expected to have a significant
impact on TXU Electric.
To meet these SO2 requirements, the Clean Air Act provides for the annual
allocation of SO2 emission allowances to utilities. Under the Clean Air Act,
utilities are permitted to transfer allowances within their own systems and to
buy or sell allowances from or to other utilities. The EPA grants a maximum
number of allowances annually to TXU Electric based on the amount of emissions
from units in operation during the period 1985 through 1987. TXU Electric
intends to utilize internal allocation of emission allowances within its system
and, if cost effective, may purchase additional emission allowances to enable
both existing and future electric generating units to meet the requirements of
the Clean Air Act. TXU Electric may also sell excess emission allowances. TXU
Electric is unable to predict the extent to which it may generate excess
allowances or will be able to acquire allowances from others if needed but does
not anticipate any significant problems in keeping emissions within its allotted
allowances.
TXU Electric's generating units meet the NOx limits currently required by the
Clean Air Act. The TNRCC and the EPA have proposed rules that will require NOx
emission reductions at TXU Electric's generating units in the Dallas-Fort Worth
area. Additionally, in 1996, TXU Electric elected for an early opt-in under
Phase I related to NOx limits for its coal-fired generating units. This election
locks in NOx limits for these generating units for a ten-year period. The Clean
Air Act also requires studies, which began in 1991, by the EPA to assess the
potential for toxic emissions from utility boilers. TXU Electric is unable to
predict either the results of such studies or the effects of any subsequent
regulations. Recently, the EPA issued proposed rules for regional haze; the
impact of these proposed rules, if adopted, is unknown at this time.
In December 1997, the Conference of the Parties of the United Nations
Framework Convention on Climate Change adopted the Kyoto Protocol, which
specifies targets and timetables for certain countries to reduce greenhouse gas
emissions. TXU Electric is unable to predict whether the Kyoto Protocol will be
ratified by the United States Senate and to what extent, if any, such protocol
might impact TXU Electric.
In 1997, the Clean Air Act required some companies to submit Title V
Operating Permit applications for many of their facilities, including TXU
Electric's generating facilities. All required Title V Operating Permit
applications have been filed and TXU Electric has received Title V Operating
Permits for many of its facilities. TXU Electric anticipates the approval of all
pending permit applications.
Major air pollution control provisions of the 1999 Restructuring Legislation
require a 50% reduction in NOx emissions from "grandfathered" electric utility
generating units and a 25% reduction in SO2 emissions from "grandfathered"
electric utility generating units. This legislation also provides for an "opt-
in" of permitted units as an alternative for achieving the same reductions and
recovery of reasonable environmental improvement costs as stranded costs upon
approval by the PUC.
The TNRCC has also recently proposed revisions to its State Implementation
Plan (SIP) rules that would require an approximately 88% reduction in NOx
emissions from electric utility units in the Dallas-Fort Worth ozone non-
attainment area. The costs of SIP reductions are eligible for recovery as
stranded costs provided they satisfy
11
the standards for recovery of environmental improvement costs established by the
1999 Restructuring Legislation provisions.
Additional Clean Air Act regulations have been proposed and others are not
yet finalized by the EPA. TXU Electric believes that the requirements necessary
to be in compliance with additional EPA regulatory provisions probably can be
met as they are developed. Estimates for the capital requirements related to the
Clean Air Act are included in TXU Electric's estimated construction
expenditures. TXU Electric currently believes that if the rules and regulations
under the Clean Air Act are adopted as proposed, operating costs that will be
incurred under operating permits, new permit fee structures, capital
expenditures associated with equipment modifications to reduce emissions, or any
expenditures on monitoring equipment, in the aggregate, will not have a
materially adverse effect on TXU Electric's financial position, results of
operations or cash flows.
Water -- The TNRCC, the EPA and the Railroad Commission of Texas (RRC) have
jurisdiction over water discharges (including storm water) from all domestic
facilities. TXU Electric's facilities are presently in compliance with
applicable state and federal requirements relating to discharge of pollutants
into the water. TXU Electric has obtained all required waste water discharge
permits from the TNRCC, the EPA and the RRC for facilities in operation and has
applied for or obtained necessary permits for facilities under construction. TXU
Electric believes it can satisfy the requirements necessary to obtain any
required permits or renewals.
Other -- Diversion, impoundment and withdrawal of water for cooling and other
purposes are subject to the jurisdiction of the TNRCC. TXU Electric possesses
all necessary permits for these activities from the TNRCC for its present
operations.
Treatment, storage and disposal of solid and hazardous waste are regulated at
the state level under the Texas Solid Waste Disposal Act (Texas Act) and at the
federal level under the Resource Conservation and Recovery Act of 1976, as
amended, (RCRA) and the Toxic Substances Control Act (TSCA). The EPA has issued
regulations under the RCRA and TSCA, and the TNRCC and the RRC have issued
regulations under the Texas Act applicable to TXU Electric's facilities. TXU
Electric has registered solid waste disposal sites and has obtained or applied
for such permits as are required by such regulations.
Under the federal Low-Level Radioactive Waste Policy Act of 1980, as amended,
the State of Texas is required to provide, either on its own or jointly with
other states in a compact, for the disposal of all low-level radioactive waste
generated within the state. The State of Texas has agreed to a compact with the
States of Maine and Vermont for a disposal facility that would be located in
Texas. That compact was ratified by Congress and signed by the President in
1998. The State of Texas has proposed to license a disposal site in Hudspeth
County, Texas, but in October 1998 the TNRCC denied that license application. No
appeal was taken from the denial of the license application, and that denial is
now final. The nature and extent of future efforts by the State of Texas to
provide for a disposal site are presently uncertain. TXU Electric will continue
to ship low-level waste material off-site for as long as an alternative disposal
site is available. Should existing off-site disposal become unavailable, the
low-level waste material will be stored on-site. TXU Electric's on-site storage
capacity is expected to be adequate until other off-site facilities become
available.
12
Item 2. PROPERTIES
The generating stations and other important units of property of TXU Electric
are located on lands owned primarily in fee simple. The greater portion of the
transmission and distribution lines of TXU Electric have been constructed over
lands of others pursuant to easements or along public highways and streets as
permitted by law. TXU Electric considers its rights in the realty on which its
properties are located to be adequate for their use in the conduct of its
business. Minor defects and irregularities customarily found in titles to
properties of like size and character may exist, but any such defects and
irregularities do not materially impair the use of the properties affected
thereby. TXU Electric has the right of eminent domain whereby it may, if
necessary, perfect or secure titles or gain access to privately held land used
or to be used in its operations. Utility plant of TXU Electric is generally
subject to the lien of its mortgage.
At December 31, 1999, TXU Electric owned or leased and operated the following
generating units:
Net
Electric Generating
Generating Capability
Units Fuel Source (MW) Percent
- ------------ ----------- ---------- -------
54 Natural Gas/Oil (a).............................. 11,980 (c) 56.9
9 Lignite/Coal..................................... 5,825 27.6
2 Nuclear.......................................... 2,300 10.9
15 Combustion Turbines (b).......................... 975 4.6
------ -----
Total......................................... 21,080 100.0
====== =====
______________
(a) Twenty-four natural gas units are capable of operating on fuel oil for
short periods when gas supplies are interrupted or curtailed. In addition,
five natural gas units are capable of operating on fuel oil for extended
periods. This includes ten 2MW diesel engine driven generators.
(b) Natural gas units leased and operated by TXU Electric. Such units are
capable of operating on fuel oil for extended periods.
(c) TXU Electric has announced plans to sell 17 natural gas-fired units at six
plants with an aggregate net generating capability of 3,116 MW.
Item 3. LEGAL PROCEEDINGS
TXU Electric is party to lawsuits arising in the ordinary course of its
business. TXU Electric believes, based on its current knowledge and the advice
of counsel, that the ultimate resolution of all such lawsuits and resulting
claims would not have a material adverse effect on its financial position,
results of operations or cash flows.
Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.
13
PART II
Item 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
All of TXU Electric's common stock is owned by TXU Corp. Reference is made
to Note 8 to Financial Statements regarding limitations upon payment of
dividends on common stock of TXU Electric.
Item 6. SELECTED FINANCIAL DATA
The information required hereunder for TXU Electric is set forth under
Selected Financial Data included in Appendix A to this report.
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
The information required hereunder for TXU Electric is set forth under
Management's Discussion and Analysis of Financial Condition and Results of
Operations included in Appendix A to this report.
Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The information required hereunder for TXU Electric is set forth in
Management's Discussion and Analysis of Financial Condition and Results of
Operations included in Appendix A to this report.
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information required hereunder for TXU Electric is set forth under
Statement of Responsibility, Independent Auditors' Report, Statements of
Consolidated Income, Statements of Consolidated Comprehensive Income, Statements
of Consolidated Cash Flows, Consolidated Balance Sheets, Statements of
Consolidated Common Stock Equity and Notes to Financial Statements included in
Appendix A to this report.
Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
14
PART III
Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF REGISTRANT
Identification of Directors, business experience and other directorships:
Other Positions and
Offices Presently Held Date First Elected as Present Principal Occupation or
With TXU Electric Director Employment and Principal
(Current Term Expires (Current Term Expires Business (Preceding Five Years),
Name of Director Age in May, 2000) in May, 2000) Other Directorships
- --------------------- --- --------------------------- --------------------- ------------------------------------
T. L. Baker 54 President, Electric February 20, 1987 President, Electric Service Division
Service Division of TXU Electric, TXU Gas
Distribution and TXU SESCO;
prior thereto, Executive Vice
President of TXU Electric; prior
thereto, Senior Vice President of
TXU Electric.
David W. Biegler 53 President and Chief August 29, 1997 President and Chief Operating Officer
Operating Officer of TXU Corp., TXU Electric and
TXU Gas; prior thereto, Chairman,
President and Chief Executive
Officer of TXU Gas; other
directorships: TXU Gas, Chase
Bank of Texas N.A. and Trinity
Industries, Inc. (railcars,
construction materials and
industrial equipment).
Barbara B. Curry 45 None August 29, 1997 Executive Vice President of TXU
Business Services; prior thereto,
Vice President of TXU Business
Services and, prior thereto,
Assistant to the Chairman of TXU
Corp.; other directorship: TXU
Gas.
M. S. Greene 54 President, Transmission May 27, 1997 President, Transmission Division of
Division TXU Electric; prior thereto,
Executive Vice President of TXU
Fuel and TXU Mining.
Michael J. McNally 45 None February 16, 1996 Executive Vice President and
Chief Financial Officer of TXU
Corp.; prior thereto President,
Transmission Division of TXU
Electric; prior thereto, Principal
of Enron Development Corporation;
prior thereto, Managing Director of
Enron Capital and Trade
Resources; other directorship: TXU
Gas.
15
Other Positions and
Offices Presently Held Date First Elected as Present Principal Occupation or
With TXU Electric Director Employment and Principal
(Current Term Expires (Current Term Expires Business (Preceding Five Years),
Name of Director Age in May, 2000) in May, 2000) Other Directorships
- --------------------- --- --------------------------- --------------------- ------------------------------------
Erle Nye 62 Chairman of the Board and September 17, 1982 Chairman of the Board and Chief
Chief Executive Executive of TXU Corp., TXU
Electric and TXU Gas; prior
thereto, President and Chief
Executive of TXU Corp. and
Chairman of the Board and Chief
Executive of TXU Electric; other
directorships: TXU Corp., TXU
Gas and TXU Europe Limited.
W. M. Taylor 57 President, Generation May 20, 1986 President, Generation Division of TXU
Division Electric and Executive Vice
President of TXU Mining; prior
thereto, Executive Vice President
of TXU Electric.
Directors of TXU Electric receive no compensation in their capacity as Directors
of TXU Electric.
Identification of Executive Officers and business experience:
Positions and Offices Date First Elected to
Presently Held (Current Present Offices
Term Expires (Current Term Expires Business Experience
Name of Officer Age in May, 2000) in May, 2000) (Preceding Five Years)
- ---------------- --- ------------------------- --------------------- -------------------------
Erle Nye 62 Chairman of the Board and February 20, 1987 Chairman of the Board and Chief
Chief Executive Executive of TXU Corp., TXU
Electric and TXU Gas; prior
thereto, President and Chief
Executive of TXU Corp. and
Chairman of the Board and Chief
Executive of TXU Electric.
David W. Biegler 53 President and Chief January 1, 1998 President and Chief Operating Officer
Operating Officer of TXU Corp., TXU Electric and
TXU Gas; prior thereto Chairman,
President and Chief Executive
Officer of TXU Gas.
T. L. Baker 54 President, Electric February 16, 1996 President, Electric Service Division
Service Division of TXU Electric, TXU Gas
Distribution and TXU SESCO;
prior thereto, Executive Vice
President of TXU Electric; prior
thereto, Senior Vice President of
TXU Electric.
M. S. Greene 54 President, Transmission May 27, 1997 President, Transmission Division of
Division TXU Electric; prior thereto,
Executive Vice President of TXU
Fuel and TXU Mining.
W. M. Taylor 57 President, Generation February 16, 1996 President, Generation Division of TXU
Division Electric and Executive Vice
President of TXU Mining; prior
thereto, Executive Vice President
of TXU Electric.
16
There is no family relationship between any of the above-named Directors and
Executive Officers.
SECTION 16(a) BENEFICIAL OWNERSHIP REPORTING COMPLIANCE
All required reports relating to changes in beneficial ownership of shares of
TXU Electric have been timely filed.
Item 11. EXECUTIVE COMPENSATION
TXU Electric and its affiliates have paid or awarded compensation during the
last three calendar years to the following Executive Officers for services in
all capacities:
SUMMARY COMPENSATION TABLE
Long-Term Compensation (4)
----------------------------------
Annual Compensation Awards Payouts
----------------------------- --------------------- -------
Other Restricted Securities All Other
Annual Stock Underlying LTIP Compen-
Name and Salary Bonus Compen- Awards Options/ Payouts sation
Principal Position Year ($) ($) (3) sation ($) ($) SARs (#) ($) ($) (5)
------------------ ---- ------- ------- --------- ---------- ---------- ------- ---------
Erle Nye, (1)............. 1999 908,333 475,000 - 688,750 - 61,016 184,892
Chairman of the Board 1998 818,750 350,000 - 541,250 - 19,674 156,906
and Chief Executive 1997 760,417 325,000 - 499,375 - 23,928 143,963
David W. Biegler, (2)..... 1999 641,667 164,000 - 310,250 - 0 81,509
President and Chief 1998 617,500 102,500 - 244,250 - 0 174,208
Operating Officer 1997 245,833 0 - 0 - 0 0
W. M. Taylor,............. 1999 375,000 98,500 - 184,000 - 24,969 70,720
President, Generation 1998 360,500 75,000 - 157,800 - 7,733 63,421
Division 1997 339,583 83,000 - 161,750 - 9,343 59,948
T. L. Baker,.............. 1999 355,833 116,000 - 199,250 - 23,467 71,675
President, Electric 1998 323,083 60,000 - 135,600 - 8,212 62,011
Service Division 1997 294,583 71,000 - 139,625 - 10,619 56,603
M. S. Greene,............. 1999 255,833 63,500 - 122,200 - 18,304 51,454
President, Transmission 1998 245,833 50,000 - 106,250 - 5,645 45,875
Division 1997 233,750 53,000 - 107,000 - 6,609 40,668
_______________
(1) Amounts reported in the table for Mr. Nye consist entirely of compensation
paid by TXU Corp.
(2) Mr. Biegler was elected to his current position with TXU Electric effective
January 1, 1998; compensation amounts represent compensation paid by TXU
Corp.
(3) Amounts reported as Bonus in the Summary Compensation Table are attributable
to the named officer's participation in the Annual Incentive Plan (AIP).
Elected corporate officers of TXU Corp. and its participating subsidiaries
with a title of Vice President or above are eligible to participate in the
AIP. Under the terms of the AIP, target incentive awards ranging from 40%
to 75% of base salary, and a maximum award of 100% of base salary, are
established. The percentage of the target or the maximum actually awarded,
if any, is dependent upon the attainment of per share net income goals
established in advance by the
17
Organization and Compensation Committee (Committee) as well as the
Committee's evaluation of the participant's and TXU Corp.'s performance.
One-half of each such award is paid in cash and is reflected as Bonus in the
Summary Compensation Table. Payment of the remainder of the award is
deferred under the Deferred and Incentive Compensation Plan (DICP) discussed
hereinafter in footnote (4).
(4) Amounts reported as Long-Term Compensation in the Summary Compensation Table
are attributable to the named officer's participation in the DICP. Elected
corporate officers of TXU Corp. and its participating subsidiaries with the
title of Vice President or above are eligible to participate in the DICP.
Participants in the DICP may defer a percentage of their base salary not to
exceed a maximum percentage determined by the Committee for each Plan year
and in any event not to exceed 15% of the participant's base salary. Salary
deferred under the DICP is included in amounts reported as Salary in the
Summary Compensation Table. TXU Corp. makes a matching award (Matching
Award) equal to 150% of the participant's deferred salary. In addition, one-
half of any AIP award (Incentive Award) is deferred and invested under the
DICP. The Matching Awards and Incentive Awards are subject to forfeiture
under certain circumstances. Under the DICP, a trustee purchases TXU Corp.
common stock with an amount of cash equal to each participant's deferred
salary, Matching Award and Incentive Award, and accounts are established for
each participant containing performance units (Units) equal to such number
of common shares. DICP investments, including reinvested dividends, are
restricted to TXU Corp. common stock. On the expiration of the applicable
maturity period (three years for the Incentive Awards and five years for
deferred salary and Matching Awards), the values of the participant's
accounts are paid in cash based upon the then current value of the Units;
provided, however, that in no event will a participant's account be deemed
to have a cash value which is less than the sum of such participant's
deferred salary together with a 6% per annum interest compounded annually.
The maturity period is waived if the participant dies or becomes totally and
permanently disabled and may be extended under certain circumstances.
Incentive Awards and Matching Awards that have been made under the DICP are
included under Restricted Stock Awards in the Summary Compensation Table for
each of the last three years. As a result of these awards, undistributed
Incentive Awards and Matching Awards made under the DICP in prior years, and
dividends reinvested thereon, the number and market value of such Units at
December 31, 1999 (each of which is equal to one share of common stock) held
in the DICP accounts for Messrs. Nye, Biegler, Taylor, Baker and Greene were
55,941 ($1,989,402), 13,782 ($490,122), 17,715 ($629,990), 16,358 ($581,731)
and 11,968 ($425,612), respectively.
The Long-Term Incentive Compensation Plan (LTICP) is a comprehensive, stock-
based incentive compensation plan providing for discretionary grants of
common stock-based awards, including restricted stock. Outstanding awards
to named executive officers vest over a three year period and such executive
officers may earn from 0% to 200% of the number of shares awarded based on
TXU Corp.'s total return to shareholders over this three year period
compared to the total return provided by the companies comprising the
Standard & Poor's Electric Utility Index. Dividends are paid and reinvested
on stock awards at the same rate as dividends on TXU Corp.'s common stock.
As a result of restricted stock awards under the LTICP, and reinvested
dividends, the number of shares of restricted stock and the value of such
shares at December 31, 1999 held for Messrs. Nye, Biegler, Taylor, Baker and
Greene were 90,227 ($3,208,698), 17,875 ($635,680), 16,124 ($573,410),
20,359 ($724,017), and 3,088 ($109,817), respectively.
Salary deferred under the DICP is included in amounts reported as Salary in
the Summary Compensation Table. Amounts shown in the table below represent
the number of shares purchased under the DICP with these deferred salaries
for 1999 and the number of shares awarded under the LTICP:
18
LONG-TERM INCENTIVE PLANS - AWARDS IN LAST FISCAL YEAR
Deferred and Incentive
Compensation Plan Long-Term Incentive Compensation Plan
----------------------------- ----------------------------------------------------------
Number of Performance or Performance or
Shares, Other Period Number of Other Period Estimated Future Payouts
Units or Until Shares, Units Until --------------------------
Other Rights Maturation or Other Maturation or Minimum Maximum
Name (#) or Payout Rights (#) Payout (#) (#)
---- ------------- -------------- -------------- -------------- ----------- ------------
Erle Nye........... 3,417 5 Years 40,000 3 Years 0 80,000
David W. Biegler... 2,337 5 Years 10,000 3 Years 0 20,000
W. M. Taylor....... 1,366 5 Years 7,000 3 Years 0 14,000
T. L. Baker........ 1,330 5 Years 10,000 3 Years 0 20,000
M. S. Greene....... 935 5 Years 3,000 3 Years 0 6,000
The amounts reported under LTICP Payouts in the Summary Compensation Table
represent payouts maturing during such years of earnings on deferred salary
under the DICP in prior years.
(5) Amounts reported as All Other Compensation in the Summary Compensation Table
are attributable to the named officer's participation in certain plans and
as otherwise described hereinafter in this footnote.
Employees of TXU Corp. and its participating subsidiaries are eligible to
participate in the Employees' Thrift Plan of the Texas Utilities Company
System (Thrift Plan), except for employees who, as of the last pay period in
1997, were on the payroll of ENSERCH Corporation (predecessor by name change
to TXU Gas) or a subsidiary of TXU Gas who, with certain exceptions, are
eligible to participate in the ENSERCH Corporation Employee Stock Purchase
and Savings Plan (ENSAVE Plan). Under the Thrift Plan and the ENSAVE Plan
participants may invest up to 16% of their regular salary or wages in common
stock of TXU Corp., or in a variety of selected mutual funds. The
participant's employer matches a portion of the participant's contributions
in an amount equal to 40%, 50% or 60% (depending on the participant's length
of service) of the first 6% of such participant's contributions. All
matching amounts are invested in common stock of TXU Corp. The amounts
reported under All Other Compensation in the Summary Compensation Table
include these matching amounts which, for Messrs. Nye, Biegler, Taylor,
Baker and Greene amounted to $5,760, $5,760, $5,760, $5,760 and $5,760,
respectively, during 1999.
TXU Corp. has a Salary Deferral Program (Program) under which each employee
of TXU Corp. and its participating subsidiaries whose annual salary is equal
to or greater than an amount established under the Program ($97,910 for the
Program Year beginning April 1, 1999) may elect to defer a percentage of
annual base salary, or any bonus or other special cash compensation for a
period of seven years, for a period ending with the retirement of such
employee, or for a combination thereof. Effective with the Program Year
beginning April 1, 1998, such deferrals may be up to a maximum of 50% of the
employee's annual salary and/or 100% of the employee's bonus or other
special cash compensation. TXU Corp. makes a matching award, subject to
forfeiture under certain circumstances, equal to 100% of up to the first 8%
of salary deferred under the Program. Prior to April 1, 1998, deferrals
under the Program were limited to up to 10% of the employee's salary and TXU
Corp. made a matching award equal to 100% of the employee's salary deferral.
Salary and bonuses deferred under the Program are included in amounts
reported under Salary and Bonus, respectively, in the Summary Compensation
Table. Deferrals made after April 1, 1998, are credited with earnings or
losses based on the performance of investment alternatives selected by each
participant. Deferrals made prior to April 1, 1998, are, at the end of the
applicable maturity period, credited with the greater of the actual earnings
of the Program assets, or the average yield during the applicable maturity
period of U.S. Treasury Notes having a maturity of ten years. At the end of
the applicable maturity period, the trustee for the Program distributes the
deferrals and the applicable earnings in cash. The distribution is in a
lump sum if the applicable maturity period is seven years. If the
retirement option is elected, the distribution is made in twenty annual
installments. Individuals who were participating in the Program on
19
March 31, 1998, were given a one time opportunity to elect (1) to continue
to have the provisions of the Program relating to permitted deferrals,
matching awards, investments and calculation of earnings in effect prior to
April 1, 1998, apply to their future Program participation; or (2) to have
the Program provisions relating to investments and calculation of earnings
apply to their entire Program account, including deferrals and matching
contributions which had been made prior to April 1, 1998. TXU Corp. is
financing the retirement portion of the Program through the purchase of
corporate-owned life insurance on the lives of the participants. The
proceeds from such insurance are expected to allow TXU Corp. to fully
recover the cost of the retirement option. During 1999, matching awards,
which are included under All Other Compensation in the Summary Compensation
Table, were made for Messrs. Nye, Biegler, Taylor, Baker and Greene in the
amounts of $72,667, $51,333, $30,000, $28,467 and $25,583, respectively.
Under TXU Corp.'s Split-Dollar Life Insurance Program (Insurance Program),
split-dollar life insurance policies are purchased for elected corporate
officers of TXU Corp. and its participating subsidiaries with a title of
Vice President or above, with a death benefit equal to four times their
annual Insurance Program compensation. New participants vest in the policies
issued under the Insurance Program over a six year period. TXU Corp. pays
the premiums for these policies and has received a collateral assignment of
the policies equal in value to the sum of all of its insurance premium
payments. Although the Insurance Program is terminable at any time, it is
designed so that if it is continued, TXU Corp. will fully recover all of the
insurance premium payments it has made either upon the death of the
participant or, if the assumptions made as to policy yield are realized,
upon the later of fifteen years of participation or the participant's
attainment of age sixty-five. During 1999, the economic benefit derived by
Messrs. Nye, Biegler, Taylor, Baker and Greene from the term insurance
coverage provided and the interest foregone on the remainder of the
insurance premiums paid by TXU Corp. amounted to $106,465, $24,416, $34,960,
$37,448 and $20,111, respectively.
As a part of the acquisition of TXU Gas, options to purchase the common
stock of TXU Gas which had been granted to various employees of TXU Gas were
converted into options to acquire common shares of TXU Corp. The table below
shows, for each of the named officers, the information specified with respect to
exercised, exercisable and unexercisable options under all existing stock option
plans, converted into shares of TXU Corp.'s common stock into which such options
became exercisable at the time of the TXU Gas acquisition.
AGGREGATED OPTION EXERCISES IN LAST FISCAL YEAR
Number of Securities Value of Unexercised
Underlying Unexercised In-the-Money
Shares Options at Options at
Acquired on Value December 31, 1999 December 31, 1999
Exercise Realized (#) ($)
-------------------------- --------------------------
Name (#) ($) Exercisable Unexercisable Exercisable Unexercisable
---- ------------ --------- ----------- ------------- ----------- -------------
Erle Nye.......... 0 0 0 0 0 0
David W. Biegler.. 0 0 129,778 0 1,463,332 0
W. M. Taylor...... 0 0 0 0 0 0
T. L. Baker....... 0 0 0 0 0 0
M. S. Greene...... 0 0 0 0 0 0
TXU Corp. and its subsidiaries maintain retirement plans (TU Retirement
Plan) which are qualified under applicable provisions of the Internal Revenue
Code of 1986, as amended (Code). Annual retirement benefits under the
traditional defined benefit formula of the TU Retirement Plan, which applied to
each of the named officers, are computed as follows: for each year of accredited
service up to a total of 40 years, 1.3% of the first $7,800, plus 1.5% of the
excess over $7,800, of the participant's average annual earnings during his or
her three years of highest earnings. Amounts reported under Salary for the named
officers in the Summary Compensation Table approximate earnings as defined by
the TU Retirement Plan without regard to any limitations imposed by the Code.
Benefits paid
20
under the TU Retirement Plan are not subject to any reduction for Social
Security payments but are limited by provisions of the Code. As of February 29,
2000, years of accredited service under the TU Retirement Plan for Messrs. Nye,
Biegler, Taylor, Baker and Greene were 37, 2, 32, 29 and 29, respectively.
TEXAS UTILITIES PENSION PLAN TABLE
Years of Service
------------------------------------------------------------------
REMUNERATION 20 25 30 35 40
- ------------ ---------- -------- -------- ---------- ----------
$ 50,000 $ 14,688 $ 18,360 $ 22,032 $ 25,704 $ 29,376
100,000 29,688 37,110 44,532 51,954 59,376
200,000 59,688 74,610 89,532 104,454 119,376
400,000 119,688 149,610 179,532 209,454 239,376
800,000 239,688 299,610 359,532 419,454 479,376
1,000,000 299,688 374,610 449,532 524,454 599,376
1,400,000 419,688 524,610 629,532 734,454 839,376
1,800,000 539,688 674,610 809,532 944,454 1,079,376
2,000,000 599,688 749,610 899,532 1,049,454 1,199,376
Before the TXU Gas acquisition, Mr. Biegler earned retirement benefits
under the Retirement and Death Benefit Program of 1969 of ENSERCH Corporation
and Participating Subsidiary Companies (ENSERCH Retirement Plan) which was
merged into, and became a part of, the TU Retirement Plan effective December 31,
1997. In connection with this plan merger, the TU Retirement Plan was amended
to provide that the retirement benefit of employees who were employed by TXU Gas
or one of its subsidiaries participating in the ENSERCH Retirement Plan on
August 5, 1997, and as of the last full pay period of 1997, will equal the sum
of (1) their accrued benefit under the ENSERCH Retirement Plan through the last
pay period of 1997 and (2) their accrued benefit under the TU Retirement Plan
beginning with the first pay period of 1998; provided that the aggregate
retirement benefit earned under the traditional defined benefit plan formula of
the plans can be no less than the retirement benefit which would have been
earned had all service under the traditional defined benefit formula been under
the ENSERCH Retirement Plan. Mr. Biegler, whose employment with TXU Corp. began
August 5, 1997, is treated in a similar manner. Amounts reported for Mr.
Biegler under Salary and Bonus in the Summary Compensation Table approximate
earnings as defined by the ENSERCH Retirement Plan without regard to any
limitations imposed by the Code. Benefits paid under the ENSERCH Retirement Plan
are not subject to any reduction for Social Security payments but are limited by
provisions of the Code. As of February 28, 1999, Mr. Biegler had 29 years of
accredited service under the ENSERCH Retirement Plan and 2 years of accredited
service under the TU Retirement Plan.
ENSERCH PENSION PLAN TABLE
Years of Service
--------------------------------------------------------------------------------------
REMUNERATION 20 25 30 35 40 45
- ------------ -------- -------- ---------- ---------- ---------- ----------
$ 50,000 $ 12,541 $ 15,676 $ 18,812 $ 21,947 $ 23,197 $ 24,447
100,000 30,041 37,551 45,062 52,572 55,072 57,572
200,000 65,041 81,301 97,562 113,822 118,822 123,822
400,000 135,041 168,801 202,562 236,322 246,322 256,322
800,000 275,041 343,801 412,562 481,322 501,322 521,322
1,000,000 345,041 431,301 517,562 603,822 628,822 653,822
1,400,000 485,041 606,301 727,562 848,822 883,822 918,822
1,800,000 625,041 781,301 937,562 1,093,822 1,138,822 1,183,822
2,000,000 695,041 868,801 1,042,562 1,216,322 1,266,322 1,316,322
21
TXU Corp.'s supplemental retirement plans (Supplemental Plan) provide for
the payment of retirement benefits which would otherwise be limited by the Code
or the definition of earnings in the TU Retirement Plan or the ENSERCH
Retirement Plan, as applicable. Under the Supplemental Plan, retirement
benefits are calculated in accordance with the same formula used under the
applicable qualified plan, except that, with respect to calculating the portion
of the Supplemental Plan benefit attributable to service under the TU Retirement
Plan, earnings also include AIP awards (50% of the AIP award is reported under
Bonus for the named officers in the Summary Compensation Table). The tables set
forth above illustrate the total annual benefit payable at retirement under the
TU Retirement Plan and the ENSERCH Retirement Plan, respectively, inclusive of
benefits payable under the Supplemental Plan, prior to any reduction for a
contingent beneficiary option which may be selected by participants.
The following report and performance graph are presented herein for
information purposes only. This information is not required to be included
herein and shall not be deemed to form a part of this report to be "filed" with
the Securities and Exchange Commission. The report set forth hereinafter is the
report of the Organization and Compensation Committee of the Board of Directors
of TXU Corp. and is illustrative of the methodology utilized in establishing the
compensation of executive officers of TXU Corp. and TXU Electric. References in
the report to the "Company" are references to TXU Corp.
22
ORGANIZATION AND COMPENSATION COMMITTEE REPORT
ON EXECUTIVE COMPENSATION
The Organization and Compensation Committee of the Board of Directors
(Committee) is responsible for reviewing and establishing the compensation of
the executive officers of the Company. The Committee consists of all of the
nonemployee directors of the Company and is chaired by James A. Middleton. The
Committee has directed the preparation of this report and has approved its
contents and submission to the shareholders.
As a matter of policy, the Committee believes that levels of executive
compensation should be based upon an evaluation of the performance of the
Company and its officers generally, as well as in comparison to persons with
comparable responsibilities in similar business enterprises. Compensation plans
should align executive compensation with returns to shareholders with due
consideration accorded to balancing both long-term and short-term objectives.
The overall compensation program should provide for an appropriate and
competitive balance between base salaries and performance-based annual and long-
term incentives. The Committee has determined that, as a matter of policy to be
implemented over time, the base salaries of the officers will be established at
the median, or 50th percentile, of the top ten electric utilities in the United
States and that opportunities for total direct compensation (defined as the sum
of base salaries, annual incentives and long-term incentives) to reach the 75th
percentile, or above, of such utilities will be provided through performance-
based compensation plans. Such compensation principles and practices have
allowed, and should continue to allow, the Company to attract, retain and
motivate its key executives.
In furtherance of these policies, a nationally recognized compensation
consultant has been retained since 1994 to assist the Committee in its periodic
reviews of compensation and benefits provided to officers. The consultant's
evaluations include comparisons to the largest utilities as well as to general
industry with respect both to the level and composition of officers'
compensation. The consultant's recommendations including the Annual Incentive
Plan, the Long-Term Incentive Compensation Plan and certain benefit changes have
generally been implemented. The Annual Incentive Plan, which was first approved
by the shareholders in 1995 and is being resubmitted this year, is generally
referred to as the AIP and is described in this report, in footnote 3 to the
Summary Compensation Table. The Long-Term Incentive Compensation Plan, referred
to as the Long-Term Plan or LTICP, was approved by the shareholders in 1997 and
is described in this report as well as in footnote 4 to the Summary Compensation
Table.
The compensation of the officers of the Company consists principally of base
salaries, the opportunity to participate in the Deferred and Incentive
Compensation Plan (referred to as the DICP and described in footnote 4 to the
Summary Compensation Table), the opportunity to earn an incentive award under
the AIP and, in certain instances, awards of performance-based restricted shares
under the Long-Term Plan. The value of future payments under the DICP, as well
as the value of the deferred portion of any award under the AIP and the value of
any awards of performance-based restricted shares under the Long-Term Plan, is
directly related to the future performance of the Company's common stock. It is
anticipated that performance-based incentive awards under the AIP and the Long-
Term Plan, will, in future years, continue to constitute a substantial
percentage of the officers' total compensation.
Certain of the Company's business units have developed separate annual and
long-term incentive compensation plans. Those plans focus on the results
achieved by those individual business units and the compensation opportunities
provided by those plans are considered to be competitive in the markets in which
those units compete. Generally, officers may not participate in both the
traditional incentive compensation plans as discussed herein and the business
unit plans. None of the named officers participate in the individual business
unit plans.
The AIP is administered by the Committee and provides an objective framework
within which annual Company and individual performance can be evaluated by the
Committee. Depending on the results of such performance evaluations, and the
attainment of the per share net income goals established in advance, the
23
Committee may provide annual incentive compensation awards to eligible officers.
The evaluation of each individual participant's performance is based upon the
attainment of individual and business unit objectives. The Company's
performance is evaluated, compared to the ten largest electric utilities and/or
the electric utility industry, based upon its total return to shareholders and
return on invested capital, as well as other measures relating to
competitiveness, service quality and employee safety. The combination of
individual and Company performance results, together with the Committee's
evaluation of the competitive level of compensation which is appropriate for
such results, determines the amount, if any, actually awarded.
As required by Section 162(m) of the Internal Revenue Code relating to the
deductibility of compensation, the AIP is being submitted for reapproval by the
shareholders. Detailed information concerning the proposal to reapprove the AIP
is contained in the Company's proxy statement. It is important to note that the
principal terms of the plan will remain unchanged. The reapproval is being
requested simply to comply with the Internal Revenue Code. The Committee
believes that the AIP is an important and appropriate component of officers'
compensation and recommends that the shareholders vote in favor of reapproval.
The Long-Term Plan, which is also administered by the Committee, is a
comprehensive stock-based incentive compensation plan under which all awards are
made in, or based on the value of, the Company's common stock. The Long-Term
Plan provides that, in the discretion of the Committee, awards may be in the
form of stock options, stock appreciation rights, performance and/or restricted
stock or stock units or in any other stock-based form. The purpose of the Long-
Term Plan is to provide performance-related incentives linked to long-term
performance goals. Such performance goals may be based on individual performance
and/or may include criteria such as absolute or relative levels of total
shareholder return, revenues, sales, net income or net worth of the Company, any
of its subsidiaries, business units or other areas, all as the Committee may
determine. Awards under the Long-Term Plan are expected to constitute the
principal long-term component of officers' compensation.
In establishing levels of executive compensation at its May 1999 meeting,
the Committee reviewed various performance and compensation data, including the
performance measures under the AIP and the report of its compensation
consultant. Information was also gathered from industry sources and other
published and private materials which provided a basis for comparing the largest
electric and gas utilities and other survey groups representing a large variety
of business organizations. Included in the data considered were the comparative
returns provided by the largest electric and gas utilities as represented by the
returns of the Standard & Poor's Electric Utility Index which are reflected in
the graph herein. Compensation amounts were established by the Committee based
upon its consideration of the above comparative data and its subjective
evaluation of Company and individual performance at levels consistent with the
Committee's policy relating to total direct compensation.
At its meeting in May 1999, the Committee provided awards of performance-
based restricted stock under the Long-Term Plan to certain officers, including
the Chief Executive. The future value of those awards will be determined by the
Company's total return to shareholders over a three year period compared to the
total return for that period of the companies comprising the Standard & Poor's
Electric Utility Index. Depending upon the Company's relative return for such
period, the officers may earn from 0% to 200% of the original award and their
compensation is, thereby, directly related to shareholder value. Awards granted
in May 1999 contemplate that 200% of the original award will be provided if the
Company's total return is in the 81st percentile or above of the returns of the
companies comprising the Standard & Poor's Electric Utility Index and that such
percentage of the original award will be reduced as the Company's return
compared to the Index declines so that 0% of the original award will be provided
if the Company's return is in the 40th percentile or below of returns provided
by the companies comprising the Index. These awards, and any awards that may be
made in the future, are based upon the Committee's evaluation of the appropriate
level of long-term compensation consistent with its policy relating to total
direct compensation.
In May 1999, the Committee increased Mr. Nye's base salary as Chief
Executive to an annual rate of $950,000 representing a $100,000 or 11.8%
increase over the amount established for Mr. Nye in May of 1998. Based upon the
Committee's evaluation of individual and Company performance, as called for by
the AIP, the Committee also provided Mr. Nye with an AIP award of $950,000
compared to the prior year's award of $700,000.
24
The Committee also awarded 40,000 shares of performance-based restricted stock
to Mr. Nye. Under the terms of the award, Mr. Nye can earn from 0% to 200% of
the award depending on the Company's total return to shareholders over a three-
year period (April 1, 1999 through March 31, 2002) compared to the total return
provided by the companies comprising the Standard & Poor's Electric Utility
Index. This level of compensation was established based upon the Committee's
subjective evaluation of the information described in this report.
In discharging its responsibilities with respect to establishing executive
compensation, the Committee normally considers such matters at its May meeting
held in conjunction with the Annual Meeting of Shareholders. Although Company
management may be present during Committee discussions of officers'
compensation, Committee decisions with respect to the compensation of the
Chairman of the Board and Chief Executive and the President are reached in
private session without the presence of any member of Company management.
As noted, Section 162(m) of the Code limits the deductibility of
compensation which a publicly traded corporation provides to its most highly
compensated officers. As a general policy, the Company does not intend to
provide compensation which is not deductible for federal income tax purposes.
Awards under the AIP in 1996 and subsequent years have been fully deductible
and, assuming shareholder reapproval of the plan, are expected to continue to
be deductible. Awards under the Long-Term Plan are expected to be fully
deductible, and the DICP and the Salary Deferral Program have been amended to
require the deferral of distributions of amounts earned in 1995 and subsequent
years until the time when such amounts would be deductible. Awards provided
under the AIP in 1995 and distributions under the DICP and the Salary Deferral
Program which were earned in plan years prior to 1995, may not be fully
deductible but such amounts are not expected to be material.
Organization and Compensation Committee
James A. Middleton, Chair Margaret N. Maxey
Derek C. Bonham J. E. Oesterreicher
William M. Griffin Charles R. Perry
Kerney Laday Herbert H. Richardson
25
PERFORMANCE GRAPH
The following graph compares the performance of the Company's common stock
to the S&P 500 Index and S&P Electric Utility Index for the last five years.
The graph assumes the investment of $100 at December 31, 1994 and that all
dividends were reinvested. The amount of the investment at the end of each year
is shown in the graph and in the table which follows.
Cumulative Total Returns
for the Five Years Ended 12/31/99
[GRAPH APPEARS HERE]
----------------------------------
1994 1995 1996 1997 1998 1999
- ----------------------------------------------------------------------
Texas Utilities ................. 100 139 145 156 185 150
- ----------------------------------------------------------------------
S&P 500 Index..................... 100 138 169 226 290 351
- ----------------------------------------------------------------------
S&P Electric Utility Index........ 100 131 131 165 190 154
- ----------------------------------------------------------------------
26
Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Security ownership of certain beneficial owners at March 6, 2000:
Amount and Nature
Name and Address of Beneficial
Title of Class of Beneficial Owner Ownership Percent of Class
-------------- ------------------- ------------------- -----------------
Common stock, Texas Utilities Company 101,249,700 shares 100.0%
without par value, Energy Plaza sole voting and
of TXU Electric 1601 Bryan Street investment power
Dallas, Texas 75201
Security ownership of management at March 6, 2000:
The following lists the common stock of TXU Corp. owned by the Directors
and Executive Officers of TXU Electric. The named individuals have sole voting
and investment power for the shares of common stock reported. Ownership of such
common stock by the Directors and Executive Officers, individually and as a
group, constituted less than 1% of the outstanding shares at March 6, 2000. None
of the named individuals own any of the preferred stock of TXU Electric or the
preferred securities of any subsidiaries of TXU Electric.
Number of Shares
----------------------------------------------------------
Name Beneficially Owned Deferred Plan (1) Total
---- ------------------- ----------------- -----
T. L. Baker.................. 24,755 23,235 47,990
David W. Biegler............. 163,963 (2) 18,886 182,849
Barbara B. Curry............. 5,991 9,423 15,414
M. S. Greene................. 5,061 17,223 22,284
Michael J. McNally........... 51,809 23,431 75,240
Erle Nye..................... 127,727 73,869 201,596
W. M. Taylor................. 29,107 25,303 54,410
------- ------- -------
All Directors and Executive
Officers as a group (7).... 408,413 191,370 599,783
======= ======= =======
_________________
(1) Share units held in deferred compensation accounts under the Deferred and
Incentive Compensation Plan. Although this plan allows such units to be paid
only in the form of cash, investments in such units create essentially the
same investment stake in the performance of TXU Corp.'s common stock as do
investments in actual shares of common stock.
(2) Shares reported include 129,778 shares subject to stock options exercisable
within six months of the record date.
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
27
PART IV
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
Page
----
(a) Documents filed as part of this Report:
Financial Statements (included in Appendix A to this report):
Selected Financial Data - Consolidated Financial and Operating Statistics............ A-2
Management's Discussion and Analysis of Financial Condition
and Results of Operations.......................................................... A-4
Statement of Responsibility.......................................................... A-11
Independent Auditors' Report......................................................... A-12
Statements of Consolidated Income for each of the three years in the
period ended December 31, 1999..................................................... A-13
Statements of Consolidated Comprehensive Income for each of the
three years in the period ended December 31, 1999.................................. A-13
Statements of Consolidated Cash Flows for each of the three years in
the period ended December 31, 1999................................................. A-14
Consolidated Balance Sheets, December 31, 1999 and 1998.............................. A-15
Statements of Consolidated Common Stock Equity for each of the three years in
the period ended December 31, 1999................................................. A-17
Notes to Financial Statements........................................................ A-18
The consolidated financial statement schedules are omitted because of the
absence of the conditions under which they are required or because the required
information is included in the consolidated financial statements or notes
thereto.
(b) Reports on Form 8-K:
Reports on Form 8-K filed since September 30, 1999, are as follows:
Date of Report Item Reported
-------------- -------------
October 5, 1999 Item 5. Other Events
October 22, 1999 Item 5. Other Events
March 13, 2000 Item 5. Other Events
(c) Exhibits:
Included in Appendix B to this report.
28
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, TXU Electric Company has duly caused this report to be
signed on its behalf by the undersigned, thereunto duly authorized.
TXU ELECTRIC COMPANY
Date: March 17, 2000 By: /s/ ERLE NYE
-----------------------------------------
(Erle Nye, Chairman of the Board and
Chief Executive)
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of TXU Electric
Company and in the capacities and on the date indicated.
Signature Title Date
--------- ----- ----
/s/ ERLE NYE Principal Executive
- --------------------------------------------------------
(Erle Nye, Chairman of the Board and Chief Executive) Officer
/s/ KIRK R. OLIVER Principal Financial
- --------------------------------------------------------
(Kirk R. Oliver, Treasurer and Assistant Secretary) Officer
/s/ JERRY W. PINKERTON Principal Accounting Officer
- --------------------------------------------------------
(Jerry W. Pinkerton, Controller)
/s/ T. L. BAKER Director
- --------------------------------------------------------
(T. L. Baker)
/s/ DAVID W. BIEGLER Director
- --------------------------------------------------------
(David W. Biegler)
/s/ BARBARA B. CURRY Director March 17, 2000
- --------------------------------------------------------
(Barbara B. Curry)
/s/ M. S. GREENE Director
- --------------------------------------------------------
(M. S. Greene)
/s/ MICHAEL J. McNALLY Director
- --------------------------------------------------------
(Michael J. Mcnally)
/s/ W. M. TAYLOR Director
- --------------------------------------------------------
(W. M. Taylor)
29
Appendix A
TXU ELECTRIC COMPANY AND SUBSIDIARIES
INDEX TO FINANCIAL INFORMATION
December 31, 1999
Page
Selected Financial Data - Consolidated Financial and Operating
Statistics............................................................................ A- 2
Management's Discussion and Analysis of Financial Condition and
Results of Operations................................................................. A- 4
Statement of Responsibility............................................................ A-11
Independent Auditors' Report........................................................... A-12
Financial Statements:
Statements of Consolidated Income and Comprehensive Income............................. A-13
Statements of Consolidated Cash Flows.................................................. A-14
Consolidated Balance Sheets............................................................ A-15
Statements of Consolidated Common Stock Equity......................................... A-17
Notes to Financial Statements.......................................................... A-18
A-1
TXU ELECTRIC COMPANY AND SUBSIDIARIES
SELECTED FINANCIAL DATA
CONSOLIDATED FINANCIAL STATISTICS
Year Ended December 31,
----------------------------------------------------------
1999 1998 1997 1996 1995
---------- ---------- ---------- ---------- ----------
(Millions of Dollars, except ratios)
Total assets -- end of year................................. $18,108 $18,405 $18,824 $18,795 $19,003
- -----------------------------------------------------------------------------------------------------------------------
Electric plant - gross -- end of year....................... $24,123 $23,583 $23,132 $22,664 $22,748
Accumulated depreciation and amortization -- end of year.. 8,044 7,338 6,576 5,963 5,371
Reserve for regulatory disallowances -- end of year....... 836 836 836 836 1,308
Construction expenditures................................. 554 496 443 376 403
- -----------------------------------------------------------------------------------------------------------------------
Capitalization -- end of year
Long-term debt, less amounts due currently................ $ 4,684 $ 5,208 $ 5,476 $ 6,311 $ 7,212
TXU Electric Company obligated, mandatorily redeemable,
preferred securities of subsidiary trusts holding solely
junior subordinated debentures of TXU Electric Company
(trust securities)....................................... 824 823 875 381 381
Preferred stock:
Not subject to mandatory redemption..................... 115 115 129 465 490
Subject to mandatory redemption......................... 21 21 21 238 263
Common stock equity....................................... 6,671 6,495 6,298 6,106 5,800
------- ------- ------- ------- -------
Total.................................................. $12,315 $12,662 $12,799 $13,501 $14,146
======= ======= ======= ======= =======
- -----------------------------------------------------------------------------------------------------------------------
Capitalization ratios -- end of year
Long-term debt, less amounts due currently................ 38.0% 41.1% 42.8% 46.8% 51.0%
Trust securities.......................................... 6.7 6.5 6.8 2.8 2.7
Preferred stock........................................... 1.1 1.1 1.2 5.2 5.3
Common stock equity....................................... 54.2 51.3 49.2 45.2 41.0
------- ------- ------- ------- -------
Total.................................................. 100.0% 100.0% 100.0% 100.0% 100.0%
======= ======= ======= ======= =======
- -----------------------------------------------------------------------------------------------------------------------
Embedded interest cost on long-term debt -- end of year..... 7.4% 8.3% 8.3% 8.3% 8.4%
Embedded distribution cost on trust securities -- end of
year....................................................... 8.4% 8.4% 8.3% 8.7% 8.6%
Embedded dividend cost on preferred stock -- end of year*... 11.0% 13.5% 14.1% 7.5% 7.4%
- -----------------------------------------------------------------------------------------------------------------------
Net income available for common stock....................... $ 769 $ 785 $ 745 $ 809 $ 368
Dividends declared on common stock.......................... -- -- 137 503 682
Common stock repurchased and retired........................ 593 578 416 -- --
- -----------------------------------------------------------------------------------------------------------------------
Ratio of earnings to fixed charges.......................... 3.2 3.3 2.9 3.0 2.0
Ratio of earnings to combined fixed charges and preferred
dividends.................................................. 3.1 3.1 2.7 2.6 1.7
Return on average common stock equity....................... 11.7% 12.3% 12.0% 13.6% 6.2%
- -----------------------------------------------------------------------------------------------------------------------
*Includes the unamortized balance of the loss on reacquired preferred stock and
associated amortization. The embedded dividend cost, excluding the effects of
the loss on reacquired preferred stock, is 6.7% for 1999, 6.7% for 1998, 6.9%
for 1997, 6.8% for 1996 and 6.9% for 1995.
Certain previously reported financial statistics have been reclassified to
conform to current classifications.
A-2
TXU ELECTRIC COMPANY AND SUBSIDIARIES
CONSOLIDATED OPERATING STATISTICS
Year Ended December 31,
------------------------------------------------------
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
ELECTRIC ENERGY GENERATED AND
PURCHASED (gigawatt hours - GWh)
Generated-- net station output............................... 94,575 97,574 91,298 88,130 83,876
Purchased and net interchange................................ 11,464 11,271 11,443 12,418 10,684
------- ------- ------- ------- ------
Total generated and purchased........................... 106,039 108,845 102,741 100,548 94,560
Company use, losses and unaccounted for...................... 6,554 6,484 6,161 5,805 5,532
------- ------- ------- ------- ------
Total electric energy sales............................. 99,485 102,361 96,580 94,743 89,028
======= ======= ======= ======= ======
ELECTRIC ENERGY SALES (GWh)
Residential.................................................. 35,155 36,830 33,530 33,039 30,716
Commercial................................................... 29,736 29,332 27,323 26,456 25,553
Industrial................................................... 24,715 25,125 24,609 24,215 23,302
Government and municipal..................................... 6,515 6,525 6,039 5,929 5,616
------- ------- ------- ------- ------
Total general business.................................. 96,121 97,812 91,501 89,639 85,187
Other electric utilities..................................... 3,364 4,549 5,079 5,104 3,841
------- ------- ------- ------- ------
Total electric energy sales............................. 99,485 102,361 96,580 94,743 89,028
======= ======= ======= ======= ======
OPERATING REVENUES (millions of dollars)
Base rate revenues
Residential............................................. $2,042 $2,157 $1,991 $1,994 $1,875
Commercial.............................................. 1,336 1,307 1,235 1,227 1,194
Industrial.............................................. 577 583 582 590 586
Government and municipal................................ 318 317 293 291 280
------- ------- ------- ------- ------
Total general business............................. 4,273 4,364 4,101 4,102 3,935
Other electric utilities................................ 105 138 164 166 133
------- ------- ------- ------- ------
Total base rate business........................... 4,378 4,502 4,265 4,268 4,068
Fuel (including over/under-recovered)........................ 1,701 1,798 1,707 1,679 1,422
Transmission service......................................... 148 126 114 -- --
Other........................................................ 72 62 49 83 70
------- ------- ------- ------- ------
Subtotal............................................... 6,299 6,488 6,135 6,030 5,560
Earnings in excess of earnings cap........................... (92) -- -- -- --
------- ------- ------- ------- ------
Total operating revenues............................... $6,207 $6,488 $6,135 $6,030 $5,560
======= ======= ======= ======= ======
DEGREE DAYS (% of normal)
Cooling..................................................... 114 130 94 115 100
Heating..................................................... 70 89 106 94 91
ELECTRIC CUSTOMERS (end of year-- in thousands)
Residential................................................. 2,266 2,206 2,152 2,110 2,061
Commercial.................................................. 251 244 237 230 225
Industrial.................................................. 21 21 21 21 21
Government and municipal.................................... 32 31 31 30 30
------- ------- ------- ------- ------
Total electric customers............................... 2,570 2,502 2,441 2,391 2,337
======= ======= ======= ======= ======
RESIDENTIAL STATISTICS (excludes master-metered
customers, kilowatt hour (kWh) sales, and revenues)
Average annual kWh per customer............................ 14,875 16,170 15,026 15,100 14,336
Average revenue per kWh.................................... 7.59(cent) 7.83(cent) 7.85(cent) 7.91(cent) 8.08(cent)
________________
Industrial classification includes service to Alcoa-Sandow:
Electric energy sales (GWh)................................ 3,845 3,779 3,820 3,842 3,765
Operating revenues (millions of dollars)................... $ 41 $ 40 $ 47 $ 47 $ 48
Certain previously reported operating statistics have been reclassified to
conform to current classifications.
A-3
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
BUSINESS
TXU Electric Company (TXU Electric), formerly Texas Utilities Electric
Company, is an electric utility engaged in the generation, purchase,
transmission, distribution and sale of electric energy solely within the State
of Texas. TXU Electric is a wholly-owned subsidiary of Texas Utilities Company
(doing business as TXU Corp.), a Texas corporation. TXU Corp. is a holding
company that, through its subsidiaries, is engaged in the generation, purchase,
transmission, distribution and sale of electricity; the gathering, processing,
transmission and distribution of natural gas; energy marketing; and
telecommunications, retail energy services, international gas operations, power
development and other businesses primarily in the United States (US), Europe and
Australia. As an integrated electric utility, TXU Electric currently has only
one reportable segment. TXU Electric possesses all necessary franchises,
licenses and certificates to enable it to conduct its business.
In October 1999, TXU Electric announced plans to sell six of its eighteen
natural gas-fired electricity generating plants in Texas. These plants have an
aggregate generating capacity of 3,116 megawatts (MW), or approximately 15% of
TXU Electric's generating capacity. Any gain on the sale of these plants will be
recorded as a regulatory liability and applied against TXU Electric's generation
assets that may become stranded costs under provisions of the electric utility
restructuring legislation passed in the 1999 session of the Texas Legislature
(1999 Restructuring Legislation). (See Note 3 to Financial Statements.) TXU
Electric plans to sell the plants, together with all associated assets,
including land, lakes, water rights, air permits, emission allowances and fuel
transportation contracts. TXU Electric anticipates entering into a tolling
agreement with the new owners to receive the capacity and energy from these
plants for a portion of the peak load season of 2001, and purchasing any
remaining requirements on the open market. TXU Electric anticipates completion
of the plant sales by the end of 2000.
RESULTS OF OPERATIONS
Significant Items
1999 1998 1997
---- ---- ----
(Millions of Dollars)
Fuel Disallowance/Sale of Sulfur
Dioxide Allowances:
Reduction of revenues......................................... $ 52 $ -- $ 79
Increase in interest expense.................................. -- -- 12
Tax benefit................................................... (21) -- (36)
----- ----- -----
Net earnings reduction................................. $ 31 $ -- $ 55
----- ----- -----
Impact of Earnings Cap:
Reduction of revenues......................................... $ 92 $ -- $ --
Additional nuclear depreciation............................... 52 170 --
Tax benefit................................................... (54) (27) --
----- ----- -----
Net earnings reduction................................. $ 90 $ 143 $ --
----- ----- -----
A-4
1999 versus 1998
- ----------------
Net income of $779 million for the year ended 1999 was 2.4% lower than
1998. Comparisons of net income were impacted by both a fuel reconciliation
settlement that reduced 1999 net income by $31 million and a rate settlement
agreement that became effective in January 1998 and was modified by the 1999
Restructuring Legislation, which reduced customer rates and introduced an
earnings cap.
From January 1, 1998 through June 30, 1999, earnings in excess of the
earnings cap were recorded as additional depreciation of nuclear production
assets. Effective July 1, 1999, following the 1999 Restructuring Legislation,
earnings in excess of the earnings cap were recorded as a reduction of revenues,
with a corresponding regulatory liability recorded. Mitigation as a result of
the earnings cap reduced net income by $90 million in 1999 and $143 million in
1998.
Additionally, from January 1, 1998 through June 30, 1999, depreciation
expense was reclassified from transmission and distribution (T&D) to nuclear
production assets. Effective July 1, 1999, following the 1999 Restructuring
Legislation, T&D depreciation expense was no longer transferred to nuclear
production assets; instead an amount equivalent to T&D depreciation was recorded
as a regulatory asset, with an offsetting amount recorded as a regulatory
liability. The regulatory asset will be amortized as it is recovered through the
Distribution portion of the business, while the regulatory liabilities will be
applied against stranded generation assets. (See Note 13 to Financial
Statements.) Additional nuclear mitigation in 1999 was $336 million, including
$144 million to reduce earnings to the earnings cap, $95 million of depreciation
expense reclassified from T&D to nuclear production assets and an amount
equivalent to $97 million of T&D depreciation expense recorded as a regulatory
asset. Since January 1998, regular nuclear depreciation and additional nuclear
mitigation total approximately $1.3 billion.
In June 1999, TXU Electric reached an agreement with all intervening
parties to refund $52 million to consumers as part of a fuel reconciliation
proceeding with the Public Utility Commission of Texas (PUC). The refund, which
was recorded as a reduction of revenues, was approximately 1% of the $5.04
billion spent by TXU Electric during the period from July 1, 1995 through June
30, 1998 for fuel to generate electricity and appeared as a one-time credit on
customer bills during the September 1999 billing cycle.
Excluding the reduction of revenues as a result of the earnings cap and
fuel reconciliation disallowance, operating revenues for 1999 were 2.1% lower
than 1998. Revenues in 1999 were $160 million less than 1998 due to the impact
of the exceptionally hot summer weather in 1998. Cooling degree days in 1999
were 114% of normal compared to 130% of normal in 1998. Heating degree days in
1999 were 70% of normal compared to 89% of normal in 1998. An additional
reduction in rates effective January 1, 1999 due to the 1998 rate settlement
agreement was somewhat offset by continued strong core retail sales and revenue
growth. Electric energy sales volumes for 1999 were 2.8% lower than 1998. Fuel
revenues for 1999 were slightly lower than in 1998, primarily as a result of
lower energy sales.
Operation and maintenance expenses for 1999 were 4% higher than 1998
largely as a result of increased transmission expenses due to increased PUC
third party transmission tariffs. Depreciation and amortization expense was $108
million lower in 1999 versus 1998. Mitigation depreciation recorded in 1999 was
$52 million versus $170 million in 1998.
The net decrease of $52 million in interest expense and other charges for
1999 compared to 1998 is primarily due to the reacquisition of long-term debt
and remarketing of certain debt to lower interest rates.
A-5
The effective income tax rate for TXU Electric was lower in 1999 compared
to 1998 due primarily to the discontinuation of amortization of prior period
flow-through amounts and other tax-related regulatory assets and liabilities
resulting from the impact of the 1999 Restructuring Legislation.
1998 versus 1997
- ----------------
Net income of $798 million for 1998 increased approximately 3% from 1997.
Results for 1997 were reduced by an $81 million fuel disallowance (including
interest) and a $10 million charge related to the sale of sulfur dioxide
allowances, which reduced net income by $55 million. Excluding the effect of
these items, 1998 net income decreased approximately 4% from 1997. Results for
1998 were impacted by the rate reduction settlement approved by the PUC in April
1998 that became effective January 1, 1998, and increased nuclear depreciation
net of associated income taxes that reduced 1998 income by $143 million. These
effects were partially offset by continued strong sales growth and the effect of
exceptionally hot summer weather in 1998.
Operating revenues increased approximately 6% for 1998 as compared to 1997
primarily due to an increase in base rate electricity revenues due to the
exceptionally high summer temperatures (cooling degree days in 1998 were 130% of
normal compared to 94% of normal in 1997) and customer growth, partially offset
by the effect of the rate reduction settlement on base rate revenues. Electric
energy sales in gigawatt-hours (GWh), including unbilled sales, were
approximately 6% higher in 1998 compared to 1997. Fuel revenue, excluding the
fuel disallowance in 1997 increased slightly in 1998, primarily due to increases
in fuel costs driven by increased energy sales.
Energy purchased for resale and fuel consumed increased approximately 2%,
primarily due to increased energy sales, with increased gas usage partially
offset by decreased gas prices in 1998. Total operating expenses, excluding
energy purchased for resale and fuel consumed, increased approximately 12% for
1998 compared to 1997 largely as a result of higher marketing incentives,
increased provision for uncollectible accounts and increased reactive
maintenance expenses, partially offset by decreased employee-related costs. TXU
Electric's rate reduction settlement resulted in additional nuclear depreciation
of $353 million in 1998. Of the additional nuclear depreciation in 1998, $183
million was the result of the transfer of T&D depreciation and $170 million was
the result of earnings in excess of the earnings cap. Taxes other than income
increased in 1998 primarily due to higher state and local gross receipt taxes.
Total interest expense and other charges decreased approximately 9% in
1998 compared with 1997. The capital restructuring and debt reduction programs
favorably affected the year-to-year comparison. Distributions on trust
securities and preferred stock dividends decreased from 1997, reflecting the
redemption of trust securities and repurchases of preferred stock.
The effective income tax rate was higher for 1998 than 1997 due to the
impact of amortization of prior-period flow-through amounts, which increased due
to the accelerated depreciation on nuclear production assets in conjunction with
the rate reduction agreement.
FINANCIAL CONDITION
Liquidity and Capital Resources
Cash flows provided by operating activities before changes in operating
assets and liabilities for 1999 were $1.7 billion compared with $1.8 billion and
$1.6 billion for 1998 and 1997, respectively. The year-to-year comparisons
reflect revenue changes discussed above in Results of Operations. Changes in
operating assets and liabilities in 1999 used $85 million versus cash provided
of $2 million and $74 million in 1998 and 1997, respectively.
Over/under-recovered fuel revenue in 1999 was impacted by a fuel refund of $97
million (excluding interest and taxes) in June 1999.
A-6
Cash flows used in financing activities were $1.0 billion, $1.2 billion
and $1.1 billion for the years 1999, 1998 and 1997, respectively. Major
financing activities in 1999 included the retirement of $731 million of
long-term debt and the repurchase of approximately $593 million of common stock.
Cash flows used in investing activities for 1999 totaled $605 million
versus $580 million for 1998 and $526 million for 1997. Construction
expenditures were $554 million, $496 million and $443 million for 1999, 1998 and
1997, respectively, and are estimated at $705 million for 2000. The increase in
the 2000 estimate compared to 1999 is due to generation-related environmental
costs, network upgrades and costs associated with the 1999 Restructuring
Legislation.
The capitalization ratios of TXU Electric at December 31, 1999 consisted
of approximately 38% long-term debt, 7% trust securities, 1% preferred stock and
54% common stock equity, compared to 1998 capitalization ratios of approximately
41% long-term debt, 7% trust securities, 1% preferred stock and 51% common stock
equity.
Financing transactions during the year ended December 31, 1999, were as
follows:
Issuances Retirements
--------- -----------
(Millions of Dollars)
Long-term Debt:
Brazos River Authority Pollution Control Bonds............. $177 $177
First Mortgage Bonds....................................... -- 551
Other...................................................... -- 3
---- ----
Total.................................................. $177 $731
==== ====
Early redemptions of preferred stock and long-term debt may occur from
time to time in amounts presently undetermined. See Notes 5, 6 and 7 to
Financial Statements for further details concerning long-term debt, trust
securities and preferred stock. TXU Electric may issue additional debt and
equity securities as needed, including the possible future sale of up to $499
million principal amount of debt securities and up to $25 million of its
Cumulative Preferred Stock, all of which are currently registered with the
Securities and Exchange Commission for offering pursuant to Rule 415 under the
Securities Act of 1933.
At December 31, 1999, TXU Corp., TXU Electric and TXU Gas Company had
joint US dollar-denominated lines of credit under revolving credit facility
agreements (US Credit Agreements) with a group of banking institutions. At
December 31, 1999, TXU Electric had no borrowings outstanding under these
facilities. The US Credit Agreements were amended and restated in February 2000
and have two facilities. Facility A provides for short-term borrowings
aggregating up to $1.4 billion outstanding at any one time at variable interest
rates and terminates February 23, 2001, but may be extended by up to one year.
Facility B provides for borrowings aggregating up to $1.4 billion outstanding at
any one time at variable interest rates and terminates February 25, 2005.
Facility B also provides for the issuance of up to $300 million of letters of
credit. TXU Electric's borrowings under both facilities are limited to an
aggregate of $1.25 billion outstanding at any one time.
A-7
Quantitative and Qualitative Disclosure About Market Risk
TXU Electric's operations involve managing market risks related to changes
in interest rates. TXU Electric enters into interest rate swaps to reduce and
manage a portion of those risks. TXU Electric's participation in derivative
transactions are designated for hedging purposes and such derivative
transactions are not entered into for trading purposes.
CREDIT RISK -- Credit risk relates to the risk of loss that TXU Electric
would incur as a result of nonperformance by counterparties to their respective
derivative instruments. TXU Electric maintains credit policies with regard to
its counterparties that management believes significantly minimize overall
credit risk. TXU Electric generally does not obtain collateral to support the
agreements but establishes credit limits and monitors the financial viability of
counterparties. In the event a counterparty's credit rating declines, TXU
Electric may apply certain remedies, if considered necessary. TXU Electric
believes the risk of nonperformance by counterparties is minimal.
ENERGY PRICE RISK -- As a result of continued regulation, TXU Electric has
minimal exposure to energy price risk, therefore, its use of derivative
instruments is limited.
INTEREST RATE RISK -- The table below provides information concerning TXU
Electric's financial instruments as of December 31, 1999 that are sensitive to
changes in interest rates, which include debt obligations, trust securities and
interest rate swaps. TXU Electric has entered into interest rate swaps under
which it has agreed to exchange the difference between fixed-rate and
variable-rate interest amounts calculated with reference to specified notional
principal amounts at dates that generally coincide with interest payments.
Weighted average variable rates are based on rates in effect at the reporting
date.
Expected Maturity Date
-----------------------------------------------------------
(Millions of Dollars) 1999 1998
There- 1999 Fair 1998 Fair
2000 2001 2002 2003 2004 after Total Value Total Value
---- ---- ---- ---- ---- ------- ----- ----- ----- -----
Long-term Debt
(including current maturities)
Fixed Rate......................... $ 509 $ 221 $ 374 $ 308 $ 225 $2,768 $4,405 $4,398 $4,992 $5,296
Average interest rate............ 5.83% 7.49% 8.23% 6.92% 7.20% 7.23% 7.14% 7.41%
Variable Rate...................... -- -- -- -- -- $ 788 $ 788 $ 788 $ 749 $ 749
Average interest rate............ -- -- -- -- -- 5.16% 5.16% 4.88%
TXU Electric obligated, mandatorily
redeemable, preferred securities of
subsidiary trusts holding solely
junior subordinated debentures of
TXU Electric
Fixed Rate......................... -- -- -- -- -- $ 727 $ 727 $ 645 $ 727 $ 765
Average interest rate............ -- -- -- -- -- 8.14% 8.14% 8.14%
Variable Rate...................... -- -- -- -- -- $ 97 $ 97 $ 97 $ 96 $ 97
Average interest rate............ -- -- -- -- -- 7.01% 7.01% 6.02%
Interest Rate Swaps
(notional amounts)
Variable to Fixed.................. -- -- $ 100 -- -- -- $ 100 $ 1 $ 100 $ (4)
Average pay rate................. -- -- 7.18% -- -- -- 7.18% 7.18%
Average receive rate............. -- -- 7.01% -- -- -- 7.01% 6.19%
A-8
NUCLEAR DECOMMISSIONING AND DISPOSAL OF SPENT FUEL TRUST -- TXU Electric
has established an external trust to provide for nuclear decommissioning and
disposal of spent fuel. The trust's assets are invested in marketable fixed
income debt and equity securities. The market value of the debt and equity
securities was $94 million and $150 million, respectively, at December 31, 1999.
At December 31, 1998, the market value of the debt and equity securities was $81
million and $130 million, respectively. A hypothetical 10% increase in interest
rates and 10% decrease in equity prices would result in a $20 million reduction
in the fair value of the trust assets. However, adjustments to market value
result in a corresponding adjustment to related liability accounts based on
current regulatory treatment.
Regulation and Rates
Electric Industry Restructuring-- Project teams have been established to
prepare TXU Electric for a competitive environment. These teams are comprised of
resources from all facets of TXU Corp.'s business. These teams continue to
formulate short- and long-term strategies to address the implementation of the
1999 Restructuring Legislation. TXU Electric continues to analyze the long-range
implications of the 1999 Restructuring Legislation on its financial position,
results of operations and cash flows.
TXU Electric anticipates that a portion of the cost of its generation
production assets and power purchase contracts may be identified as stranded
costs under the legislation and become subject to a future quantification of the
economic value of such assets. The 1999 Restructuring Legislation provides that
100% of such stranded costs will be recovered from regulated operations.
Although TXU Electric cannot predict future regulatory or legislative
actions or any changes in economic and securities market conditions, no changes
are expected in trends or commitments, other than those discussed in this Form
10-K, which might significantly alter its basic financial position, results of
operations or cash flows. For further discussion of the impact of the 1999
Restructuring Legislation, see Notes 3 and 13 to Financial Statements.
TXU Electric has several rate requests pending or on appeal, see Note 13
to Financial Statements.
YEAR 2000 ISSUES
Year 2000 (Y2K) computer related issues of TXU Electric were addressed
with those of its parent company, TXU Corp. The following disclosure is
excerpted from TXU Corp.'s Form 10-K for the year ended December 31, 1999.
Beginning in 1996, a thorough and detailed program was undertaken
throughout the TXU Corp. system to address Y2K issues. The focus was on
information technology (IT) mainframe-based application systems, IT related
hardware, operating systems and desk top software, and embedded systems such as
process controls for energy production and delivery and business-unit-owned
applications. Applications and equipment in each of these categories were
inventoried and categorized based on criticality to TXU Electric's business
operations. Assessments of potential impact due to Y2K issues were completed in
1999. Remediation and testing work in each of these areas was completed by
December 31, 1999.
During the year 2000 rollover, TXU Electric's customers experienced no
service interruptions due to computer hardware, software and imbedded chips. A
few minor problems occurred with internal systems, but these were considered to
be no more than normal system issues.
A-9
The total costs incurred through 1999 associated with TXU Corp.'s Y2K
efforts were approximately $59 million. These costs reflect new, incremental
costs and the reallocation of resources in pre-existing maintenance budgets.
These costs were expensed as incurred and a total of approximately $5 million is
expected to be spent during the year 2000. There can be no assurance that these
estimates will not change as a result of the discovery of unexpected needs for
additional remediation work.
CHANGES IN ACCOUNTING STANDARDS
Statement of Financial Accounting Standards (SFAS) No. 133 "Accounting for
Derivative Instruments and Hedging Activities", as extended, is effective for
TXU Electric beginning January 1, 2001. SFAS No. 133 establishes accounting and
reporting standards for derivative instruments, including certain derivative
instruments embedded in other contracts, and for hedging activities. It requires
the recognition of derivatives as either assets or liabilities in the statement
of financial position and the measurement of those instruments at fair value.
TXU Electric is currently evaluating the impact the adoption of this standard
will have on its financial position and results of operations.
FORWARD-LOOKING STATEMENTS
This report and other presentations made by TXU Electric contain
forward-looking statements within the meaning of Section 21E of the Securities
Exchange Act of 1934, as amended. Although TXU Electric believes that in making
any such statement its expectations are based on reasonable assumptions, any
such statement involves uncertainties and is qualified in its entirety by
reference to the following important factors, among others, that could cause the
actual results of TXU Electric to differ materially from those projected in such
forward-looking statements: (i) prevailing governmental policies and regulatory
actions, including those of the FERC, PUC and NRC, with respect to allowed rates
of return, industry and rate structure, purchased power and investment recovery,
operations of nuclear generating facilities, acquisitions and disposal of assets
and facilities, operation and construction of plant facilities, decommissioning
costs, present or prospective wholesale and retail competition, changes in tax
laws and policies and changes in and compliance with environmental and safety
laws and policies, (ii) weather conditions and other natural phenomena, (iii)
unanticipated population growth or decline, and changes in market demand and
demographic patterns, (iv) competition for retail and wholesale customers, (v)
pricing and transportation of crude oil, natural gas and other commodities, (vi)
unanticipated changes in interest rates or rates of inflation, (vii)
unanticipated changes in operating expenses and capital expenditures, (viii)
capital market conditions, (ix) competition for new energy development
opportunities, (x) legal and administrative proceedings and settlements, (xi)
inability of the various counterparties to meet their obligations with respect
to TXU Electric's financial instruments, (xii) changes in technology used and
services offered by TXU Electric, and (xiii) significant changes in TXU
Electric's relationship with its employees and the potential adverse effects if
labor disputes or grievances were to occur.
Any forward-looking statement speaks only as of the date on which such
statement is made, and TXU Electric undertakes no obligation to update any
forward-looking statement to reflect events or circumstances after the date on
which such statement is made or to reflect the occurrence of unanticipated
events. New factors emerge from time to time and it is not possible for TXU
Electric to predict all of such factors, nor can it assess the impact of each
such factor or the extent to which any factor, or combination of factors, may
cause results to differ materially from those contained in any forward-looking
statement.
A-10
TXU ELECTRIC COMPANY AND SUBSIDIARIES
STATEMENT OF RESPONSIBILITY
The management of TXU Electric Company (TXU Electric) is responsible for
the preparation, integrity and objectivity of the consolidated financial
statements of TXU Electric and its subsidiaries and other information included
in this report. The consolidated financial statements have been prepared in
conformity with generally accepted accounting principles. As appropriate, the
statements include amounts based on informed estimates and judgments of
management.
The management of TXU Electric has established and maintains a system of
internal control designed to provide reasonable assurance, on a cost-effective
basis, that assets are safeguarded, transactions are executed in accordance with
management's authorization and financial records are reliable for preparing
consolidated financial statements. Management believes that the system of
control provides reasonable assurance that errors or irregularities that could
be material to the consolidated financial statements are prevented or would be
detected within a timely period. Key elements in this system include the
effective communication of established written policies and procedures,
selection and training of qualified personnel and organizational arrangements
that provide an appropriate division of responsibility. This system of control
is augmented by an ongoing internal audit program designed to evaluate its
adequacy and effectiveness. Management considers the recommendations of the
internal auditors and independent auditors concerning TXU Electric's system of
internal control and takes appropriate actions which are cost-effective in the
circumstances. Management believes that, as of December 31, 1999, TXU Electric's
system of internal control was adequate to accomplish the objectives discussed
herein.
The independent auditing firm of Deloitte & Touche LLP is engaged to
audit, in accordance with generally accepted auditing standards, the
consolidated financial statements of TXU Electric and its subsidiaries and to
issue their report thereon.
/s/ ERLE NYE
------------------------------------------
Erle Nye, Chairman of the Board
and Chief Executive
/s/ D. W. BIEGLER
------------------------------------------
D. W. Biegler, President and
Chief Operating Officer
/s/ KIRK OLIVER
------------------------------------------
Kirk Oliver, Treasurer and Assistant
Secretary and Principal Financial Officer
/s/ JERRY W. PINKERTON
------------------------------------------
Jerry W. Pinkerton, Controller and
Principal Accounting Officer
A-11
INDEPENDENT AUDITORS' REPORT
TXU Electric Company:
We have audited the accompanying consolidated balance sheets of TXU Electric
Company, formerly known as Texas Utilities Electric Company (TXU Electric), and
subsidiaries as of December 31, 1999 and 1998, and the related consolidated
statements of income, comprehensive income, common stock equity and cash flows
for each of the three years in the period ended December 31, 1999. These
financial statements are the responsibility of TXU Electric management. Our
responsibility is to express an opinion on these financial statements 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 TXU Electric and 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.
DELOITTE & TOUCHE LLP
Dallas, Texas
February 16, 2000
A-12
TXU ELECTRIC COMPANY AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED INCOME
Year Ended December 31,
------------------------------------------
1999 1998 1997
----------- ----------- -----------
Millions of Dollars
OPERATING REVENUES......................................... $6,207 $6,488 $6,135
------ ------ ------
OPERATING EXPENSES
Energy purchased for resale and fuel consumed......... 2,081 2,102 2,063
Operation and maintenance............................. 1,333 1,281 1,226
Depreciation and amortization......................... 641 749 572
Income taxes.......................................... 362 490 420
Taxes other than income............................... 541 533 507
------ ------ ------
Total operating expenses........................ 4,958 5,155 4,788
------ ------ ------
OPERATING INCOME........................................... 1,249 1,333 1,347
------ ------ ------
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction... 8 6 5
Other income (deductions) -- net...................... (3) (12) (8)
Income tax benefit.................................... 6 4 10
------ ------ ------
Total other income (deductions).................. 11 (2) 7
------ ------ ------
INCOME BEFORE INTEREST AND OTHER CHARGES................... 1,260 1,331 1,354
====== ====== ======
INTEREST INCOME............................................ 3 3 7
INTEREST EXPENSE AND OTHER CHARGES
Interest.............................................. 425 476 527
Distributions on TXU Electric Company obligated,
mandatorily redeemable, preferred securities
of subsidiary trusts holding solely junior
subordinated debentures of TXU Electric Company.... 68 68 70
Allowance for borrowed funds used during construction
and capitalized interest........................... (9) (8) (8)
------ ------ ------
Total interest expense and other charges........ 484 536 589
------ ------ ------
NET INCOME................................................. 779 798 772
PREFERRED STOCK DIVIDENDS.................................. 10 13 27
------ ------ ------
NET INCOME AVAILABLE FOR COMMON STOCK...................... $ 769 $ 785 $ 745
====== ====== ======
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
Year Ended December 31,
----------------------------------------
1999 1998 1997
---------- ---------- ----------
Millions of Dollars
NET INCOME................................................... $ 779 $ 798 $ 772
----- ----- -----
OTHER COMPREHENSIVE INCOME (LOSS) --
Net change during period in minimum pension
liability adjustment................................ 1 (1) --
----- ----- -----
Total........................................... 1 (1) --
----- ----- -----
COMPREHENSIVE INCOME......................................... $ 780 $ 797 $ 772
===== ===== =====
See Notes to Financial Statements.
A-13
TXU ELECTRIC COMPANY AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED CASH FLOWS
Year Ended December 31,
---------------------------------------
1999 1998 1997
----------- ----------- -----------
Millions of Dollars
CASH FLOWS -- OPERATING ACTIVITIES
Net income................................................................... $ 779 $ 798 $ 772
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization (including amounts charged to fuel).......... 781 905 710
Deferred income taxes -- net............................................ 93 127 134
Investment tax credits -- net........................................... (21) (21) (21)
Allowance for equity funds used during construction..................... (8) (6) (5)
Reduction of revenues for earnings in excess of earnings cap............ 92 -- --
Changes in operating assets and liabilities:
Accounts receivable................................................ 43 153 (124)
Inventories........................................................ 23 (2) (4)
Accounts payable................................................... (39) (169) 44
Interest and taxes accrued......................................... (50) (6) 42
Other working capital.............................................. 11 (25) 83
Over/(under) - recovered fuel revenue -- net of deferred taxes..... (59) 26 (21)
Other -- net....................................................... (14) 25 54
------- ------- -------
Cash provided by operating activities.......................... 1,631 1,805 1,664
------- ------- -------
CASH FLOWS -- FINANCING ACTIVITIES
Issuances of securities:
Long-term debt.......................................................... 177 429 513
TXU Electric Company obligated, mandatorily redeemable, preferred
securities of subsidiary trusts holding solely junior subordinated
debentures of TXU Electric Company..................................... -- -- 493
Retirements/repurchases of securities:
Long-term debt.......................................................... (731) (924) (942)
Preferred stock......................................................... -- (14) (553)
TXU Electric Company obligated, mandatorily redeemable, preferred
securities of subsidiary trusts holding solely junior subordinated
debentures of TXU Electric Company..................................... -- (47) --
Common stock............................................................ (593) (578) (280)
Change in notes receivable/payable:
Affiliates.............................................................. 158 (20) 219
Other................................................................... -- -- (253)
Preferred stock dividends paid............................................... (9) (14) (36)
Common stock dividends paid.................................................. -- -- (273)
Debt premium, discount, financing and reacquisition expenses................. (29) (64) (27)
------- ------- -------
Cash used in financing activities............................. (1,027) (1,232) (1,139)
------- ------- -------
CASH FLOWS -- INVESTING ACTIVITIES
Construction expenditures................................................... (554) (496) (443)
Nuclear fuel................................................................ (54) (51) (74)
Other investments........................................................... 3 (33) (9)
------- ------- -------
Cash used in investing activities.............................. (605) (580) (526)
------- ------- -------
NET CHANGE IN CASH AND CASH EQUIVALENTS........................................... (1) (7) (1)
CASH AND CASH EQUIVALENTS -- BEGINNING BALANCE.................................... 5 12 13
------- ------- -------
CASH AND CASH EQUIVALENTS -- ENDING BALANCE....................................... $ 4 $ 5 $ 12
======= ======= =======
See Notes to Financial Statements.
A-14
TXU ELECTRIC COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
December 31,
------------------------------
1999 1998
----------- ------------
Millions of Dollars
ELECTRIC PLANT
In service:.......................................................................
Production................................................................... $15,533 $15,469
Transmission................................................................. 1,681 1,621
Distribution................................................................. 5,390 5,046
General...................................................................... 498 447
------- -------
Total.................................................................. 23,102 22,583
Less accumulated depreciation................................................ 7,409 6,789
------- -------
Electric plant in service, less accumulated depreciation............... 15,693 15,794
Construction work in progress..................................................... 191 226
Nuclear fuel (net of accumulated amortization: 1999 -- $635; 1998 -- $549)....... 171 201
Held for future use............................................................... 24 24
------- -------
Electric plant, less accumulated depreciation and amortization......... 16,079 16,245
Reserve for regulatory disallowances.............................................. (836) (836)
------- -------
Net electric plant..................................................... 15,243 15,409
------- -------
INVESTMENTS............................................................................ 612 588
------- -------
CURRENT ASSETS
Cash and cash equivalents........................................................ 4 5
Accounts receivable (net of allowance for uncollectible accounts: 1999 -- $4; 162 205
1998 -- $7).....................................................................
Inventories -- at average cost:
Materials and supplies...................................................... 158 181
Fuel stock.................................................................. 84 84
Deferred income taxes............................................................ 21 73
Prepayments and other current assets............................................. 38 36
------- -------
Total current assets.................................................. 467 584
------- -------
OTHER ASSETS
Regulatory assets -- net......................................................... 1,680 1,762
Under-recovered fuel revenue..................................................... 39 --
Deferred debits.................................................................. 67 62
------- -------
Total other assets.................................................... 1,786 1,824
------- -------
Total......................................................... $18,108 $18,405
======= =======
See Notes to Financial Statements.
A-15
TXU ELECTRIC COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
CAPITALIZATION AND LIABILITIES
December 31,
--------------------------------
1999 1998
-------------- ----------------
Millions of Dollars
CAPITALIZATION
Common stock without par value................................................... $ 3,145 $ 3,738
Stock of parent held for long-term incentive plan trust.......................... (10) (9)
Retained earnings................................................................ 3,536 2,767
Accumulated other comprehensive loss -- minimum pension liability adjustment..... -- (1)
------- -------
Total common stock equity........................................... 6,671 6,495
Preferred stock:
Not subject to mandatory redemption.......................................... 115 115
Subject to mandatory redemption.............................................. 21 21
TXU Electric Company obligated, mandatorily redeemable, preferred securities of
subsidiary trusts holding solely junior subordinated debentures of
TXU Electric Company............................................................ 824 823
Long-term debt, less amounts due currently...................................... 4,684 5,208
------- -------
Total capitalization................................................ 12,315 12,662
------- -------
CURRENT LIABILITIES
Notes payable -- affiliates..................................................... 321 163
Long-term debt due currently.................................................... 509 533
Accounts payable:
Affiliates.................................................................. 116 115
Other....................................................................... 119 157
Customers' deposits............................................................. 79 76
Taxes accrued................................................................... 139 169
Interest accrued................................................................ 113 133
Over-recovered fuel revenue..................................................... -- 52
Other current liabilities....................................................... 130 113
------- -------
Total current liabilities.......................................... 1,526 1,511
------- -------
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES
Accumulated deferred income taxes............................................... 3,340 3,307
Investment tax credits.......................................................... 515 536
Other deferred credits and noncurrent liabilities............................... 412 389
------- -------
Total deferred credits and other noncurrent liabilities............ 4,267 4,232
------- -------
COMMITMENTS AND CONTINGENCIES (Note 14)
------- -------
Total......................................................... $18,108 $18,405
======= =======
See Notes to Financial Statements.
A-16
TXU ELECTRIC COMPANY AND SUBSIDIARIES
STATEMENTS OF CONSOLIDATED COMMON STOCK EQUITY
Year Ended December 31,
-------------------------------------
1999 1998 1997
----------- ------------ ----------
Millions of Dollars
COMMON STOCK without par value -- authorized shares --
180,000,000
Balance at beginning of year......................... $3,738 $4,316 $4,732
Common stock repurchased and retired (1999 --
19,786,000 shares; 1998 -- 19,270,300 shares;
and 1997 -- 13,869,000 shares)................. (593) (578) (416)
------ ------ ------
Balance at end of year (1999 -- 103,874,700 shares;
1998 -- 123,660,700 shares; and 1997 -- 3,145 3,738 4,316
142,931,000 shares)............................ ------ ------ ------
STOCK OF PARENT HELD FOR LONG-TERM INCENTIVE
PLAN TRUST
Balance at beginning of year......................... (9) -- --
Change during the year........................... (1) (9) --
------ ------ ------
Balance at end of year............................... (10) (9) --
------ ------ ------
RETAINED EARNINGS
Balance at beginning of year......................... 2,767 1,982 1,374
Net income....................................... 779 798 772
Dividends declared on common stock............... -- -- (137)
Dividends declared on preferred stock............ (10) (13) (27)
------ ------ ------
Balance at end of year............................... 3,536 2,767 1,982
------ ------ ------
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
Balance at beginning of year......................... (1) -- --
Change during the year........................... 1 (1) --
------ ------ ------
Balance at end of year............................... -- (1) --
------ ------ ------
COMMON STOCK EQUITY....................................... $6,671 $6,495 $6,298
====== ====== ======
See Notes to Financial Statements.
A-17
TXU ELECTRIC COMPANY AND SUBSIDIARIES
NOTES TO FINANCIAL STATEMENTS
1. BUSINESS
TXU Electric Company (TXU Electric), formerly Texas Utilities Electric
Company, is an electric utility engaged in the generation, purchase,
transmission, distribution and sale of electric energy solely within the State
of Texas. As an integrated electric utility, TXU Electric has only one
reportable segment. TXU Electric is a wholly-owned subsidiary of Texas Utilities
Company (doing business as TXU Corp.), a Texas corporation. TXU Corp. is a
holding company that, through its subsidiaries, is engaged in the generation,
purchase, transmission, distribution and sale of electricity; the gathering,
processing, transmission and distribution of natural gas; energy marketing; and
telecommunications, retail energy services, international gas operations, power
development and other businesses primarily in the United States, Europe and
Australia.
2. SIGNIFICANT ACCOUNTING POLICIES
Consolidation -- The consolidated financial statements of TXU Electric
include all of its business trusts. Certain previously reported amounts have
been reclassified to conform to current classifications. All dollar amounts in
the financial statements and notes to financial statements are stated in
millions of dollars unless otherwise indicated.
Use of Estimates -- The preparation of TXU Electric's consolidated
financial statements requires management to make estimates and assumptions about
future events that affect the reporting and disclosure of assets and liabilities
at the balance sheet dates and the reported amounts of revenue and expense
during the periods. In the event estimates and/or assumptions prove to be
different from actual amounts, adjustments are made in subsequent periods to
reflect more current information. No material adjustments, other than those
disclosed elsewhere herein, were made to previous estimates during the current
year.
System of Accounts -- The accounting records of TXU Electric are
maintained in accordance with the Federal Energy Regulatory Commission's (FERC)
Uniform System of Accounts as adopted by the Public Utility Commission of Texas
(PUC).
Regulatory Assets and Liabilities -- The financial statements of TXU
Electric reflect regulatory assets and liabilities under cost-based rate
regulation in accordance with Statement of Financial Accounting Standards (SFAS)
No. 71, "Accounting for the Effects of Certain Types of Regulation." As a result
of the electric utility restructuring legislation passed by the 1999 Texas
Legislature (1999 Restructuring Legislation), the electricity generation portion
of TXU Electric's business no longer meets the criteria to apply SFAS No. 71.
See Notes 3 and 13.
Property, Plant and Equipment -- Electric utility plant is stated at
original cost less certain regulatory disallowances. The cost of property
additions to electric utility plant (transmission, distribution and generation
prior to July 1, 1999) includes labor and materials, applicable overhead and
payroll-related costs and an allowance for funds used during construction
(AFUDC). Other property is stated at cost.
Interest Capitalized and Allowance For Funds Used During Construction --
AFUDC is a cost accounting procedure whereby amounts based upon interest charges
on borrowed funds and a return on equity capital used to finance construction
are added to utility plant.
A-18
Prior to July 1, 1999, TXU Electric capitalized AFUDC for all of its
expenditures for ongoing construction work in progress and nuclear fuel in
process not otherwise allowed in rate base by regulatory authorities. Because of
the 1999 Restructuring Legislation, effective July 1, 1999, TXU Electric began
recording AFUDC only on transmission and distribution (T&D) construction work in
progress, and interest during construction of generation assets has been
capitalized as appropriate. For 1999, 1998 and 1997, TXU Electric used AFUDC
rates of 9.0%, 8.0% and 7.9%, respectively.
Depreciation of Property, Plant and Equipment -- Depreciation of electric
utility plant is generally based upon an amortization of the original cost of
depreciable properties (net of regulatory disallowances) on a straight-line
basis over the estimated service lives of the properties. Depreciation also
includes an amount for decommissioning costs for TXU Electric's nuclear powered
electric generating station (Comanche Peak) which is being accrued over the
lives of the units. Depreciation of all other plant and equipment generally is
determined by the straight-line method over the estimated useful life of the
asset. Depreciation as a percent of average depreciable property for TXU
Electric approximated 2.9% for 1999, 3.0% for 1998 and 2.6% for 1997.
Valuation of Long-lived Assets -- TXU Electric evaluates the carrying
value of long-lived assets to be held and used when events and circumstances
warrant such a review. The carrying value of long-lived assets is considered
impaired when the projected undiscounted cash flows are less than carrying
value. In that event, a loss would be recognized based on the amount by which
the carrying value exceeds the fair market value. Fair market value is
determined primarily by available market valuations or, if applicable,
discounted cash flows.
Amortization of Nuclear Fuel and Refueling Outage Costs -- The
amortization of nuclear fuel in the reactors (net of regulatory disallowances)
is calculated on the units-of-production method and is included in nuclear fuel
expense. TXU Electric accrues a provision for costs anticipated to be incurred
during the next scheduled refueling outage for Comanche Peak, as permitted by
the PUC.
Derivative Instruments -- TXU Electric does not enter into derivative
financial instruments for trading purposes. TXU Electric enters into interest
rate swaps to reduce exposure to interest rate fluctuations. Amounts paid or
received under interest rate swap agreements are accrued as interest rates
change and are recognized over the life of the agreements as adjustments to
interest expense.
Revenues -- Electric sales revenues are recognized when services are
provided to customers on the basis of periodic cycle meter readings and include
an estimated accrual for the value of electricity provided from the meter
reading date to the end of the period. Electric revenues include billings under
approved rates and adjustments under various mechanisms to recover or refund the
cost of fuel and purchased power costs that are above or below the level
included in base rates. (See Note 13 for a discussion of Regulation and Rates.)
Income Taxes --TXU Electric is included in the consolidated federal income
tax return of TXU Corp. and subsidiary companies, and federal income taxes are
allocated to subsidiaries based upon their respective taxable income or loss.
Investment tax credits are amortized to income over the estimated service lives
of the properties. Deferred income taxes are provided for temporary differences
between the book and tax basis of assets and liabilities. Certain provisions of
SFAS No. 109 provide that regulated enterprises are permitted to recognize such
adjustments as regulatory tax assets or tax liabilities if it is probable that
such amounts will be recovered from, or returned to, customers in future rates.
Consolidated Cash Flows -- For purposes of reporting cash and cash
equivalents, temporary cash investments purchased with a remaining maturity of
three months or less are considered to be cash equivalents.
Affiliates -- TXU Corp. provides common stock capital and a part of
short-term financing requirements to TXU Electric and other subsidiaries. TXU
Corp. has other subsidiaries that perform specialized services for TXU Electric
and other subsidiaries; TXU Business Services Company, which provides financial,
accounting, information
A-19
technology, environmental, customer, procurement, personnel, shareholder and
other administrative services at cost; TXU Fuel Company (TXU Fuel), which owns a
natural gas pipeline system, acquires, stores and delivers fuel gas and provides
other fuel services at cost for the generation of electric energy by TXU
Electric; and TXU Mining Company (TXU Mining), which owns, leases and operates
fuel production facilities for the surface mining and recovery of lignite at
cost for use at TXU Electric's generating stations. TXU Electric provides
services such as energy sales, wheeling and scheduling to TXU SESCO Company, an
electric utility subsidiary of TXU Corp. operating in the eastern and central
part of Texas. (See Note 15.)
TXU Electric has entered into agreements with TXU Fuel for the procurement
of certain fuels and related services and with TXU Mining for the procurement
and production of lignite. Payments are at cost for the services received and
are required by the agreements to be "at least equivalent in the aggregate to
the annual charge to income on the books" of TXU Fuel and of TXU Mining. TXU
Electric, in effect, guarantees the principal, $325 million at December 31,
1999, and interest on long-term notes of TXU Mining through payments described
above. Such notes mature at various dates through 2005 and have interest rates
ranging from 6.5% to 7.0%.
Changes in Accounting Standards -- SFAS No. 133, "Accounting for
Derivative Instruments and Hedging Activities", as extended, is effective for
TXU Electric beginning January 1, 2001. SFAS No. 133 establishes accounting and
reporting standards for derivative instruments, including certain derivative
instruments embedded in other contracts, and for hedging activities. It requires
the recognition of derivatives as either assets or liabilities in the statement
of financial position and the measurement of those instruments at fair value.
TXU Electric is currently evaluating the impact the adoption of this standard
will have on its financial position and results of operations.
3. ACCOUNTING IMPACT OF THE RESTRUCTURING OF THE ELECTRIC UTILITY INDUSTRY IN
TEXAS
Electric Industry Restructuring -- The 1999 Restructuring Legislation,
among other matters, continues the stipulation in Docket 18490 that earnings in
excess of the earnings cap be used as mitigation to the cost of nuclear
production assets (see Note 13); authorizes competition in the retail and
generation markets for electricity beginning January 1, 2002; provides for the
recovery of generation-related and purchased power related stranded costs and
generation-related regulatory assets; requires reductions in nitrogen oxide and
sulfur dioxide emissions; requires a rate freeze for all retail customers until
January 1, 2002 and certain rate reductions for residential and small commercial
customers for up to five years thereafter; and sets certain limits on capacity
owned and controlled by power generation companies. Certain provisions of the
1999 Restructuring Legislation may be subject to different interpretation. By
September 1, 2000, each electric utility must separate from its regulated
activities its customer energy services business activities that are otherwise
already widely available in the competitive market. By January 1, 2002, each
electric utility must separate ("unbundle") its business into the following
units: a power generation company, a retail electric provider and a T&D company
or separate T&D companies. A power generation company generates electricity that
is intended to be sold at wholesale. In general, a power generation company may
not own a T&D facility and may not have a certificated service area. A retail
electric provider sells electric energy to retail customers and may not own or
operate generation assets. A T&D company may only own or operate facilities to
transmit or distribute electricity.
Accounting Impact of the Restructuring -- Regulatory Assets and
---------------------
Liabilities -- The financial statements of TXU Electric reflect regulatory
- -----------
assets and liabilities under cost-based rate regulation in accordance with SFAS
No. 71. As a result of the 1999 Restructuring Legislation, the electricity
generation portion of TXU Electric's business no longer meets the criteria to
apply regulatory accounting principles. Accordingly, application of SFAS No. 71
to the generation portion of TXU Electric's business was discontinued as of June
30, 1999. TXU Electric's T&D operations continue to meet the criteria for
recognition of regulatory assets and liabilities. The 1999 Restructuring
Legislation provides for the recovery of net generation-related regulatory
assets existing at December 31, 1998. Such generation-related regulatory assets
will be amortized as recovered through the Distribution portion of the
A-20
business. In addition, fuel costs will be fully recoverable, subject to
regulatory review, during the transition period that extends to January 1, 2002.
As a result, management believes the economic benefit of all net regulatory
assets related to the generation business will be recovered.
Generation Production Assets -- TXU Electric anticipates that a portion of
----------------------------
the cost of its generation production assets and power purchase contracts may be
identified as stranded costs under the legislation and become subject to a
future quantification of the economic value of such assets in 2004. The 1999
Restructuring Legislation provides that 100% of such stranded costs will be
recovered from customers. TXU Electric has performed an impairment analysis of
generation assets under the provisions of SFAS No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of."
SFAS No. 121 requires a company to forecast future net cash flows from operating
the asset, on an undiscounted basis excluding carrying costs, and to compare the
sum of those cash flows with the net carrying value of the asset. Under this
test, if the undiscounted net cash flows exceed the net carrying value, no
impairment exists for accounting purposes. TXU Electric has forecasted the net
cash flows of its generating assets and determined that the undiscounted net
cash flows exceed the net carrying value of those plants. Accordingly, for
accounting purposes, there is no impairment. Generation-related plant assets at
December 31, 1999 were approximately $9.7 billion, net of accumulated
depreciation. See Note 13 for further details concerning mitigation impacts.
Investment Tax Credits -- TXU Electric has unamortized deferred investment
----------------------
tax credits (ITCs) of approximately $426 million applicable to its generation
business. The unamortized ITCs are temporary differences for which a deferred
income tax asset has been recorded. Under regulatory accounting, a regulatory
liability also has been recorded. It is uncertain under applicable regulations
whether, and to what extent, the customers will ultimately benefit from the
unamortized ITCs and/or the related regulatory liability. Upon final
determination by the PUC, TXU Electric expects that the amount of unamortized
ITCs not applicable to customers will be amortized over the remaining life of
the generation plants. Also, upon final determination by the PUC, TXU Electric
expects that the regulatory liability related to the ITCs that is not applicable
to customers will be written off as an extraordinary credit to income.
4. SHORT-TERM FINANCING
TXU Electric had no borrowings from banks in 1999, 1998 or 1997 and no
commercial paper outstanding in 1999 or 1998. TXU Electric's average commercial
paper outstanding in 1997 was $37 million, with a weighted average interest rate
of 5.61%. Average borrowings outstanding from affiliates were $161 million, $206
million and $158 million during 1999, 1998, and 1997, respectively, and the
respective weighted average interest rates for such borrowings were 5.47%, 5.84%
and 5.88%. At December 31, 1999, TXU Electric had $167 million of borrowings
from affiliates outstanding at a rate of 6.24%.
At December 31, 1999, TXU Corp., TXU Electric and TXU Gas Company have
joint US dollar-denominated lines of credit under revolving credit facility
agreements (US Credit Agreements) with a group of banking institutions. At
December 31, 1999, TXU Electric had no borrowings outstanding under these
facilities. The US Credit Agreements were amended and restated in February 2000
and have two facilities. Facility A provides for short-term borrowings
aggregating up to $1.4 billion outstanding at any one time at variable interest
rates and terminates February 23, 2001, but may be extended by up to one year.
Facility B provides for short-term borrowings aggregating up to $1.4 billion
outstanding at any one time at variable interest rates and terminates February
25, 2005. Facility B also provides for the issuance of up to $300 million of
letters of credit. TXU Electric's borrowings under both facilities are limited
to an aggregate of $1.25 billion outstanding at any one time.
A-21
5. LONG-TERM DEBT
December 31,
---------------------
1999 1998
------ -------
First mortgage bonds, fixed rate (6.25% to 10.44% due 2001 to 2025)................... $2,254 $2,276
Pollution control series:
Brazos River Authority:
Fixed rate (3.7% to 7.875% due 2021 to 2033).................................. 863 902
Taxable series (6.090% due 2023) (a).......................................... 89 116
Variable rate (3.54% to 5.85% due 2022 to 2034) (b) (c)....................... 466 400
Sabine River Authority of Texas:
Fixed rate (5.55% to 8.25% due 2020 to 2022).................................. 199 199
Variable rate (4.5% to 5.25% due 2022 to 2030) (c)............................ 182 182
Trinity River Authority of Texas:
Flexible rate (5.28% to 5.55% due 2022 to 2032) (c)........................... 51 51
Secured medium-term notes, fixed rate (6.41% to 9.7% due 2001 to 2003)................ 159 315
Debt assumed for purchase of utility plant (d)........................................ 148 151
TXU Electric Floating Rate Debentures due 2000 (5.474%)............................... -- 350
TXU Electric 7.17% Senior Debentures due 2007......................................... 300 300
Unamortized premium and discount...................................................... (27) (34)
------ ------
Total long-term debt, less amounts due currently......................... $4,684 $5,208
====== ======
______________________________
(a) Interest rates in effect at December 31, 1999 are presented. Taxable
pollution control series are in a flexible rate mode. Series 1991D bonds
due 2021 are secured by an irrevocable letter of credit with maturities in
excess of one year. Series 1993 bonds due 2023 will be remarketed for
periods of less than 270 days and are secured by an irrevocable letter of
credit with maturities in excess of one year.
(b) Interest rates in effect at December 31, 1999 are presented. These series
are in a flexible mode with varying interest rates and, while in such
mode, will be remarketed for periods of less than 270 days and are secured
by an irrevocable letter of credit with maturities in excess of one year.
(c) Interest rates in effect at December 31, 1999 are presented. These series
are in a daily or multiannual mode with varying interest rates and are
supported by either municipal bond insurance policies and standby bond
purchase agreements or are secured by irrevocable letters of credit with
maturities in excess of one year.
(d) In 1990, TXU Electric purchased the ownership interest in Comanche Peak of
Tex-La Electric Cooperative of Texas, Inc. (Tex-La) and assumed debt of
Tex-La payable over approximately 32 years. The assumption is secured by a
mortgage on the acquired interest. TXU Corp. has guaranteed these
payments.
Certain variable rate debt of TXU Electric requires periodic remarketing.
Because TXU Electric intends to remarket these obligations, and has the ability
to refinance if necessary, they have been classified as long-term debt.
Sinking fund and maturity requirements for the years 2000 through 2004
under long-term debt instruments outstanding at December 31, 1999, were as
follows:
Year
----
2000 ......................................... $509
2001 ......................................... 221
2002 ......................................... 374
2003 ......................................... 308
2004 ......................................... 225
TXU Electric's first mortgage bonds are secured by a mortgage and deed of
trust with a major financial institution. Electric plant of TXU Electric is
generally subject to the lien of its mortgage.
A-22
6. TXU ELECTRIC OBLIGATED, MANDATORILY REDEEMABLE, PREFERRED SECURITIES OF
SUBSIDIARY TRUSTS HOLDING SOLELY JUNIOR SUBORDINATED EBENTURES OF TXU
ELECTRIC (TRUST SECURITIES)
Statutory business trusts have been established as wholly-owned financing
subsidiaries (Trusts) of TXU Electric for the purpose of issuing trust
securities and holding Junior Subordinated Debentures issued by TXU Electric
(Debentures). TXU Electric Capital I and III Trust Securities have a liquidation
preference of $25 per unit, and TXU Electric Capital IV and V Trust Securities
have a liquidation preference of $1,000 per unit. The only assets of each Trust
are Debentures of TXU Electric having a principal amount set forth under "Trust
Assets" in the table below. The interest on Trust assets matches the
distributions on the Trust Securities. Each Trust will use interest payments
received on the Debentures it holds to make cash distributions on the Trust
Securities it has issued.
The Trust Securities are subject to mandatory redemption upon payment of
the Debentures at maturity or upon redemption. The Debentures are subject to
redemption, in whole or in part at the option of TXU Electric, at 100% of their
principal amount plus accrued interest, after an initial period during which
they may not be redeemed and at any time upon the occurrence of certain events.
The carrying value of the Trust Securities is being increased periodically to
equal the redemption amounts at the mandatory redemption dates with a
corresponding increase in Trust Securities distributions.
The statutory business trust subsidiaries of TXU Electric had Trust
Securities outstanding as follows:
Trust Securities Trust Assets Maturity
------------------------------------------------------------ ------------------------------- --------
Units (000's) Amount Amount
----------------------------- ----------------------------- -------------------------------
1999 1998 1997 1999 1998 1997 1999 1998 1997
---- ---- ---- ---- ---- ---- ---- ---- ----
TXU Electric Capital I
(8.25% Series)......... 5,871 5,871 5,871 $ 141 $ 141 $ 141 $ 155 $ 155 $ 155 2030
TXU Electric Capital II
(9.00% Series)......... -- -- 1,991 -- -- 47 -- -- 52
TXU Electric Capital III
(8.00% Series)......... 8,000 8,000 8,000 194 194 194 206 206 206 2035
TXU Electric Capital IV
(Floating Rate Trust
Securities) (a)........ 100 100 100 97 96 98 103 103 103 2037
TXU Electric Capital V
(8.175% Series)........ 400 400 400 392 392 395 412 412 412 2037
------ ------ ------ ------ ------- ------- ------ -------- -----
Total.............. 14,371 14,371 16,362 $ 824 $ 823 $ 875 $ 876 $ 876 $ 928
====== ====== ====== ====== ======= ======= ====== ======== =====
(a) Floating rate is determined quarterly based on LIBOR. A related interest
rate swap, expiring 2002, effectively fixes the rate on the TXU Electric
Capital IV securities at 7.183%.
TXU Electric owns the securities issued by its subsidiary trusts and has
effectively issued a full and unconditional guarantee of such trusts'
securities.
A-23
7. PREFERRED STOCK
Redemption Price Per Share
(Before Adding
Shares Outstanding Amount Accumulated Dividends)
Dividend Rate December 31, December 31, December 31, 1999
- ------------- ------------------ ---------------------- ---------------------------
1999 1998 1999 1998
------ ----- ------ ------
Thousands of Shares
Not Subject to Mandatory Redemption (a):
- ----------------------------------------
$ 4.00 to $5.08 series.................. 379 379 $ 38 $ 38 $101.79 to $112.00
7.98 series........................... 261 261 26 26 (c)
7.50 series (b)....................... 308 308 30 30 (c)
7.22 series (b)....................... 221 221 21 21 (c)
----- ----- ------ ------
Total........................... 1,169 1,169 $ 115 $ 115
===== ===== ====== ======
Subject to Mandatory Redemption (d)
- -----------------------------------
$6.98 series............................ 107 107 $ 11 $ 11 (c)
6.375 series........................... 100 100 10 10 (c)
----- ----- ------ ------
Total........................... 207 207 $ 21 $ 21
===== ===== ====== ======
______________________
(a) Cumulative, without par value, entitled upon liquidation to $100 a share;
authorized 17,000,000 shares.
(b) The preferred stock series is the underlying preferred stock for depositary
shares that were issued to the public. Each depositary share represents one
quarter of a share of underlying preferred stock.
(c) Preferred stock series is not redeemable at December 31, 1999.
(d) TXU Electric is required to redeem at a price of $100 per share plus
accumulated dividends a specified minimum number of shares annually or
semi-annually on the initial/next dates shown below. These redeemable
shares may be called, purchased or otherwise acquired. Certain issues may
not be redeemed at the option of TXU Electric prior to 2003. TXU Electric
may annually call for redemption, at its option, an aggregate of up to
twice the number of shares shown below for each series at a price of $100
per share plus accumulated dividends.
Minimum Redeemable Initial/Next Date of
Series Shares Mandatory Redemption
------ ------------------ --------------------
$6.98 50,000 annually July 1, 2003
6.375 50,000 annually October 1, 2003
The carrying value of preferred stock subject to mandatory redemption is
being increased periodically to equal the redemption amounts at the
mandatory redemption dates with a corresponding increase in preferred stock
dividends.
8. COMMON STOCK EQUITY
During the years ended December 31, 1999 and 1998, TXU Electric purchased
and retired a total of 19.8 million and 19.3 million shares, respectively, of
its issued and outstanding common stock from TXU Corp. at a total cost of $593
million and $578 million, respectively. In February 2000, TXU Electric purchased
and retired approximately 2.6 million shares of its issued and outstanding
common stock at a cost of $158 million.
No shares of TXU Electric's common stock are held by or for its own
account, nor are any shares of such capital stock reserved for its officers and
employees or for options, warrants, conversions and other rights in connection
therewith.
The articles of incorporation, the mortgage of substantially all of TXU
Electric's property and certain other debt instruments of TXU Electric contain
provisions which, under certain conditions, restrict distributions on or
acquisitions of common stock. At December 31, 1999, $13 million of retained
earnings of TXU Electric were restricted as a result of such provisions.
A-24
9. INCOME TAXES
The components of the provision for income taxes are as follows:
Year Ended December 31,
----------------------------
1999 1998 1997
---- ---- ----
Charged (credited) to operating expenses
Current:
Federal................................................................ $274 $ 404 $ 283
State.................................................................. 16 29 44
------ ------ ------
Total............................................................. 290 433 327
------ ------ ------
Deferred:
Federal:
Depreciation differences and capitalized construction costs........ 84 109 147
Over/under-recovered fuel revenue.................................. 46 (14) 10
Other.............................................................. (52) (17) (43)
------ ------ ------
Total............................................................ 78 78 114
------ ------ ------
State.................................................................. 15 -- --
Investment tax credits...................................................... (21) (21) (21)
------ ------ ------
Total to operating expenses...................................... 362 490 420
------ ------ ------
Charged (credited) to other income
Current:
Federal................................................................ (36) (37) (36)
State.................................................................. (2) (2) (5)
------ ------ ------
Total............................................................. (38) (39) (41)
------ ------ ------
Deferred:
Federal:
Regulatory disallowance............................................ 31 32 34
Other.............................................................. (1) 3 14
------ ------ ------
Total............................................................. 30 35 48
------ ------ ------
State.................................................................. 2 -- (17)
------ ------ ------
Total to other income............................................. (6) (4) (10)
------ ------ ------
Total...................................................... $356 $ 486 $ 410
====== ====== ======
A-25
Reconciliation of income taxes computed at the federal statutory rate to
provision for income taxes:
Year Ended December 31,
-----------------------------
1999 1998 1997
---- ---- ----
Income before income taxes................................................... $1,135 $1,284 $1,182
====== ====== ======
Income taxes at the federal statutory rate of 35%............................ $ 397 $ 449 $ 413
Depletion allowance..................................................... (25) (24) (22)
Amortization of investment tax credits.................................. (21) (21) (21)
Amortization of tax rate differences.................................... (7) (4) (6)
Amortization of prior flow-through amounts.............................. 2 66 36
State income taxes, net of federal tax benefit.......................... 20 18 14
Other................................................................... (10) 2 (4)
------ ------ ------
Provision for income taxes................................................... $ 356 $ 486 $ 410
====== ====== ======
Effective tax rate........................................................... 31% 38% 35%
A-26
The components of TXU Electric's deferred tax assets and deferred tax
liabilities are as follows:
December 31,
--------------------------------------------------------------------
1999 1998
-------------------------------- -----------------------------
Total Current Noncurrent Total Current Noncurrent
----- ------- ---------- ----- ------- ----------
Deferred Tax Assets
Unbilled revenues......................... $ 30 $ 30 $ -- $ 30 $ 30 $ --
Over/(under)-recovered fuel revenue....... (14) (14) -- 18 18 --
Unamortized investment tax credits........ 277 -- 277 289 -- 289
Impairment of assets...................... 72 -- 72 72 -- 72
Regulatory disallowance................... 120 -- 120 152 -- 152
Alternative minimum tax................... 424 -- 424 424 -- 424
Tax rate differences...................... 71 -- 71 59 -- 59
Employee benefits......................... 111 -- 111 94 -- 94
Mitigation and redirected depreciation.... 66 -- 66 -- -- --
Deferred benefits of state income taxes... 189 4 185 178 9 169
Other..................................... 12 (1) 13 33 11 22
Deferred state income taxes............... 58 2 56 53 5 48
----- ------- ---------- ----- ------- ----------
Total deferred tax assets........... 1,416 21 1,395 1,402 73 1,329
===== ======= ========== ===== ======= ==========
Deferred Tax Liabilities
Depreciation differences and capitalized
construction costs.................... 4,072 -- 4,072 4,042 -- 4,042
Redemption of long-term debt.............. 135 -- 135 134 -- 134
Recoverable redirected depreciation....... 51 -- 51 -- -- --
Deferred charges for state income taxes... 23 -- 23 18 -- 18
Other..................................... 103 -- 103 125 -- 125
Deferred state income taxes............... 351 -- 351 317 -- 317
----- ------- ---------- ----- ------- ----------
Total deferred tax liability........ 4,735 -- 4,735 4,636 -- 4,636
----- ------- ---------- ----- ------- ----------
Net Deferred Tax Liability (Asset)........ $3,319 $ (21) $3,340 $3,234 $ (73) $3,307
===== ======= ========== ===== ======= ==========
At December 31, 1999, TXU Electric had approximately $424 million of
alternative minimum tax credit carryforwards available to offset future tax
payments.
The IRS is currently auditing the consolidated Federal Income Tax returns
of TXU Corp., which includes TXU Electric, for the years 1994 through 1996. In
management's opinion, an adequate provision has been made for any future taxes
that may be owed.
A-27
10. RETIREMENT PLAN AND OTHER POSTRETIREMENT BENEFITS
TXU Electric employees are covered by a defined benefit pensions plan that
provides benefits based on years of service and average earnings. The projected
benefit obligations for the pension plans with projected benefit obligations in
excess of plan assets were $6 million as of December 31, 1999 and $7 million as
of December 31, 1998. During 1999 certain TXU Electric employees were offered
and accepted early retirement and settlement options resulting in curtailment
losses and settlement gains. As these costs were recoverable, an offsetting
regulatory asset was recorded.
1999 1998 1997
---- ---- ----
Weighted-average assumptions:
Discount rate............................................................. 8.25% 7.00% 7.25%
Expected return on plan assets............................................ 9.00% 9.00% 9.00%
Rate of compensation increase............................................. 4.30% 4.30% 4.30%
Year Ended December 31,
-----------------------------
1999 1998 1997
---- ---- ----
Components of Net Pension Costs:
Service cost.............................................................. $ 26 $ 22 $ 21
Interest cost............................................................. 64 60 61
Expected return on assets................................................. (89) (77) (73)
Amortization of unrecognized prior service cost........................... 4 4 3
Amortization of net gain.................................................. (7) (5) (5)
Recognized settlement gains............................................... (39) -- (26)
Recognized termination benefits loss...................................... 35 -- 24
------ ----- -----
Net periodic pension cost............................................. $ (6) $ 4 $ 5
====== ===== =====
A-28
Year Ended December 31,
-----------------------
1999 1998
---- ----
Change in Pension Obligation:
Pension obligation at beginning of year............................................. $ 927 $ 845
Service cost.................................................................... 26 22
Interest cost................................................................... 64 60
Actuarial (gain)/loss........................................................... (128) 45
Benefits paid................................................................... (43) (45)
Curtailments.................................................................... 8 --
Settlements..................................................................... (108) --
Special termination benefits.................................................... 35 --
------ ------
Pension obligation at end of year................................................... $ 781 $ 927
====== ======
Change in Plan Assets:
Fair value of assets at beginning of year........................................... $1,226 $1,125
Actual return on assets......................................................... 97 146
Benefits paid................................................................... (43) (45)
Settlements..................................................................... (106) --
------ ------
Fair value of assets at end of year................................................. $1,174 $1,226
====== ======
Funded Status:
Pension obligation.................................................................. $ (781) $ (927)
Fair value of assets................................................................ 1,174 1,226
Unrecognized net transition asset................................................... (2) (2)
Unrecognized prior service cost..................................................... 29 33
Unrecognized net gain............................................................... (499) (417)
------ ------
Accrued pension cost................................................................ $ (79) $ (87)
====== ======
Amounts Recognized in the Statement of Financial Position Consist of:
Accrued benefit liability........................................................... $ (79) $ (89)
Intangible asset.................................................................... -- 1
Accumulated other comprehensive income.............................................. -- 1
------ ------
Net amount recognized........................................................... $ (79) $ (87)
====== ======
A-29
In addition to the retirement plans, TXU Electric offers certain health
care and life insurance benefits to substantially all of its employees and their
eligible dependents at retirement. Benefits received vary in level depending on
years of service and retirement dates.
1999 1998 1997
---- ---- ----
Weighted-average assumptions:
Discount rate.................................................................. 8.25% 7.00% 7.25%
Expected return on plan assets................................................. 8.49% 8.13% 7.50%
Year Ended December 31,
---------------------------
1999 1998 1997
---- ---- ----
Components of Net Periodic Postretirement Benefit Costs:
Service cost................................................................... $ 14 $ 10 $ 7
Interest cost.................................................................. 31 26 31
Expected return on assets...................................................... (9) (8) (6)
Amortization of unrecognized net transition obligation......................... 9 14 14
Amortization of net loss....................................................... 5 1 1
Recognized curtailment loss.................................................... 17 -- 4
------ ------ -----
Net postretirement benefit cost........................................... $ 67 $ 43 $ 51
====== ====== =====
Change in Postretirement Benefit Obligation:
Benefit obligation at beginning of year........................................ $ 454 $ 367
Service cost............................................................... 14 10
Interest cost.............................................................. 31 26
Participant contributions.................................................. 3 5
Actuarial (gain)/loss...................................................... (93) 76
Benefits paid.............................................................. (25) (30)
Curtailments............................................................... 12 --
------ ------
Benefit obligation at end of year.............................................. $ 396 $ 454
====== ======
Change in Plan Assets:
Fair value of assets at beginning of year...................................... $ 104 $ 82
Actual return on assets.................................................... 24 14
Employer contributions..................................................... 31 31
Participant contributions.................................................. 3 2
Benefits paid.............................................................. (25) (25)
------ ------
Fair value of assets at end of year............................................ $ 137 $ 104
====== ======
Funded Status:
Benefit obligation............................................................. $ (396) $ (454)
Fair value of assets........................................................... 137 104
Unrecognized transition obligation............................................. 115 128
Unrecognized net loss.......................................................... 1 114
------ ------
Accrued postretirement benefit cost............................................ $ (143) $ (108)
====== ======
A-30
The expected increase in costs of future benefits covered by the
postretirement benefit plans is projected using a health care cost trend rate of
5% in 2000 and thereafter. A one percentage point increase in the assumed health
care cost trend rate in each future year would increase the accumulated
postretirement benefit obligation at December 31, 1999 by approximately $41
million, and other postretirement benefits cost for 1999 by approximately $5.8
million.
11. DERIVATIVE INSTRUMENTS
TXU Electric enters into derivative instruments, primarily swaps, for
non-trading purposes only. Gains and losses on non-trading derivative
instruments effective as hedges are deferred and recorded as a component of the
underlying transaction when settled.
Interest Rate Risk Management -- TXU Electric is exposed to the market
risk inherent in fixed rate debt securities and the cash flow risk inherent in
variable rate securities. The interest rate exposure is managed through the use
of interest rate swaps. The terms of the swap outstanding at December 31, 1999
and the underlying hedged security are in Note 6.
Energy Price Risk Management -- As a result of continued regulation, TXU
Electric has minimal exposure to energy price risk, therefore, its use of
derivative instruments is limited.
Credit Risk -- Credit risk relates to the risk of loss that TXU Electric
would incur as a result of nonperformance by counterparties to their respective
derivative instruments. TXU Electric maintains credit policies with regard to
its counterparties that management believes significantly minimize overall
credit risk. TXU Electric generally does not obtain collateral to support the
agreements but establishes credit limits and monitors the financial viability of
counterparties. In the event a counterparty's credit rating declines, TXU
Electric may apply certain remedies, if considered necessary. TXU Electric
believes the risk of nonperformance by counterparties is minimal.
12. FAIR VALUE OF FINANCIAL INSTRUMENTS
The carrying amounts and related estimated fair values of TXU Electric's
significant financial instruments are as follows:
December 31, 1999 December 31, 1998
------------------- -----------------
Carrying Fair Carrying Fair
Amount Value Amount Value
------ ----- ------ -----
On balance sheet assets (liabilities)
Long-term debt (including current maturities)................. $(5,193) $(5,186) $(5,741) $(6,045)
TXU Electric obligated, mandatorily redeemable, preferred
securities of subsidiary trusts holding solely junior
subordinated debentures of TXU Electric
(824) (742) (823) (862)
Preferred stock subject to mandatory redemption............... (21) (21) (21) (21)
Off balance sheet assets (liabilities)
Financial guarantees.......................................... -- (78) -- (96)
Interest rate swap............................................ -- 1 -- (4)
The fair values of long-term debt and preferred stock subject to mandatory
redemption are estimated at the lesser of either the call price or the market
value as determined by quoted market prices, where available, or, where not
available, at the present value of future cash flows discounted at rates
consistent with comparable maturities with similar credit risk. The fair value
of Trust Securities is based on quoted market prices. The carrying amounts for
financial assets classified as current assets and the carrying amounts for
financial liabilities classified as current liabilities approximate fair value
due to the short maturity of such instruments.
A-31
Other investments primarily include deposits in an external trust fund for
nuclear decommissioning of Comanche Peak, which is carried at market value. The
trust fund is invested primarily in fixed income debt and equity securities,
which are considered as available-for-sale. Any unrealized gains or losses are
treated as regulatory assets or regulatory liabilities, respectively.
The fair value of the financial guarantees is based on the present value
of the instruments' approximate cash flows discounted at the year-end risk free
rate for issues of comparable maturities adjusted for credit risk. Fair values
for interest rate swaps are based either on quotes or the cost to terminate the
agreements. The fair values of other financial instruments for which carrying
amounts and fair values have not been presented are not materially different
than their related carrying amounts.
13. REGULATION AND RATES
Docket 9300 -- The PUC's final order (Order) in connection with TXU
Electric's January 1990 rate increase request (Docket 9300) was ultimately
reviewed by the Supreme Court of Texas (Supreme Court). As a result, an
aggregate of $909 million of disallowances with respect to TXU Electric's
reacquisitions of minority owners' interests in Comanche Peak, which had
previously been recorded as a charge to TXU Electric's earnings, has been
remanded to the District Court with instructions that it be remanded to the PUC
for reconsideration on the basis of a prudent investment standard. On remand,
the PUC also was required to reevaluate the appropriate level of TXU Electric's
construction work in progress included in rate base in light of its financial
condition at the time of the initial hearing. In connection with the settlement
of Docket 18490, proceedings in the remand of Docket 9300 have been stayed. TXU
Electric cannot predict the outcome of the reconsideration of the Order on
remand by the PUC.
Docket 18490 -- The PUC approved the non-unanimous stipulation filed on
December 17, 1997 by TXU Electric, together with the General Counsel of the PUC,
the Office of Public Utility Counsel and various other parties interested in TXU
Electric's rates and services. The stipulation, modified to incorporate changes
made by the PUC, resulted in base rate credits beginning January 1, 1998, of 4%
for residential customers, 2% for general service secondary customers and 1% for
all other retail customers, and additional base rate credits for residential
customers of 1.4% beginning January 1, 1999. Certain parties that did not sign
the stipulation have appealed the PUC's approval by filing suit in state
district court. TXU Electric cannot predict the outcome of these appeals.
In accordance with the stipulation, from January 1, 1998 through June 30,
1999, earnings in excess of the earnings cap were recorded as additional
depreciation of nuclear production assets, and a reclassification of
depreciation expense was made from T&D to nuclear production assets. As
discussed in Note 3, application of regulatory accounting principles to the
generation portion of TXU Electric's business was discontinued as of June 30,
1999. Effective July 1, 1999, earnings in excess of the earnings cap imposed by
the 1999 Restructuring Legislation were recorded as a reduction of revenues,
with a corresponding regulatory liability recorded. Upon final PUC
determination, the regulatory liability associated with earnings in excess of
the earnings cap will be applied against TXU Electric's stranded generation
assets as determined under the 1999 Restructuring Legislation's market valuation
criteria or refunded to customers.
A-32
Additionally, effective July 1, 1999, TXU Electric ceased the
reclassification of T&D depreciation expense to nuclear production assets.
Instead, an amount equal to T&D depreciation expense for the period was recorded
as a regulatory asset, which will be amortized as it is recovered through the
Distribution portion of the business. An equivalent amount was recorded as a
regulatory liability which will be applied against TXU Electric's stranded
generation assets as determined under the 1999 Restructuring Legislation's
market valuation criteria or refunded to customers.
For 1999, TXU Electric recorded $52 million as additional depreciation of
nuclear production assets and $92 million as a reduction of revenues as a result
of earnings in excess of the earnings cap, compared with $170 million of
additional depreciation of nuclear production assets for the same period in
1998. In addition, depreciation expense of $95 million for the first six months
of 1999 was reclassified from T&D to nuclear production assets and a regulatory
asset of $97 million equivalent to T&D depreciation expense was recorded for the
last half of 1999 according to the accounting treatment discussed above. Also,
$49 million of Transmission redirected depreciation has been reclassified as a
regulatory asset to conform with the 1999 Restructuring Legislation. In 1998,
depreciation expense of $183 million was reclassified from T&D to nuclear
production assets. Including deferred income tax effects, mitigation as a result
of the earnings cap reduced net income by $90 million in 1999 and $143 million
in 1998.
In August 1999, the Texas Court of Appeals issued a judgment declaring
invalid PUC rules governing open-access wholesale transmission service. These
rules, adopted in February 1996, guaranteed open-access wholesale transmission
service by electric utilities in the Electric Reliability Council of Texas
(ERCOT) to other utilities and non-utility power suppliers, and established a
rate formula to determine access charges for the transmission of wholesale
electricity. In its decision, the court concluded that the PUC lacks the
statutory authority to establish transmission access rates, and therefore
rendered the transmission rules invalid. Several interested parties and the PUC
filed motions for rehearing with the Court of Appeals, asking the court to
reverse its decision and to recognize the PUC's authority to set wholesale
transmission rates in ERCOT. In January 2000, a judgment was rendered on the
motions for rehearing by the Texas Court of Appeals, declaring that certain
subsections of the open-access rules are invalid, while still concluding that
the PUC lacks statutory authority to establish transmission access rates. TXU
Electric is unable to predict the impact of this judgment on open-access
transmission rates at this time.
Code of Conduct Rules -- In November 1999, the PUC adopted new rules
implementing the code of conduct provisions of the 1999 Restructuring
Legislation. The PUC's rules govern a utility's interactions with its
competitive affiliates and require a utility to provide all market participants
nondiscriminatory access to its regulated products and services. Additionally,
the rules prohibit a utility from subsidizing activities of an affiliate.
Separation Plan -- On January 10, 2000, TXU Electric filed with the PUC
its business separation plan as required by the 1999 Restructuring Legislation.
This plan indicates how TXU Electric proposes to separate the provision of
competitive energy services from its regulated business activities by September
1, 2000 and how it plans to unbundle into a power generation company, a retail
electric provider, and a regulated T&D utility by January 1, 2002. Although the
legal structure of these entities is not known at this time, TXU Electric
anticipates utilizing separate affiliated companies owned by a common holding
company.
Separation Costs -- On or before April 1, 2000, each electric utility must
file with the PUC a separation of its costs into competitive and regulated
components, proposed tariffs for its proposed T&D utility, and an initial
estimate of its generation-related stranded costs.
A-33
14. COMMITMENTS AND CONTINGENCIES
Clean Air Act -- The Federal Clean Air Act, as amended (Clean Air Act)
includes provisions which, among other things, place limits on the sulfur
dioxide emissions produced by generating units. TXU Electric's capital
requirements have not been significantly affected by the requirements of the
Clean Air Act.
Purchased Power Contracts -- TXU Electric has entered into purchased power
contracts to purchase power from utilities and independent power producers
through the year 2005. These contracts provide for capacity payments subject to
performance standards and energy payments based on the actual power taken under
contract. Capacity payments under these contracts for the years ended December
31, 1999, 1998 and 1997 were $227 million, $243 million and $237 million,
respectively.
Assuming operating standards are achieved, future capacity payments under
the agreements are estimated as follows:
Year
- ----
2000..................................................... $203
2001..................................................... 203
2002..................................................... 123
2003..................................................... 70
2004..................................................... 38
Thereafter............................................... 29
----
Total capacity payments............................. $666
====
Leases -- TXU Electric has entered into operating leases covering various
facilities and properties including generating plants, combustion turbines,
transportation, mining equipment, data processing equipment and office space.
Certain of these leases contain renewal and purchase options and residual value
guarantees. Lease costs charged to operating expense for the years ended
December 31, 1999, 1998 and 1997 were $89 million, $68 million and $66 million,
respectively.
At December 31, 1999, future minimum lease commitments under operating
leases that have initial or remaining noncancellable lease terms in excess of
one year as of December 31, 1999, were as follows:
Year
- ----
2000..................................................... $ 33
2001..................................................... 44
2002..................................................... 38
2003..................................................... 30
2004..................................................... 29
Thereafter............................................... 407
----
Total future minimum lease payments................. $581
====
Financial Guarantees -- TXU Electric has entered into contracts with
public agencies to purchase cooling water for use in the generation of electric
energy and has agreed, in effect, to guarantee the principal, $24 million at
December 31, 1999, and interest on bonds issued to finance the reservoirs from
which the water is supplied. The bonds mature at various dates through 2011 and
have interest rates ranging from 5-1/2% to 7%. TXU Electric is required to make
periodic payments equal to such principal and interest, including amounts
assumed by a third party and reimbursed to TXU Electric, of $4 million annually
for the years 2000 through 2003, and $7 million for 2004. Annual payments made
by TXU Electric, net of amounts assumed by a third party under such contracts,
for 1999, 1998 and 1997 were $4 million each year. In addition, TXU Electric is
obligated to pay certain variable costs of operating and maintaining the
reservoirs. TXU Electric has assigned to a municipality all contract rights and
obligations of TXU Electric in connection with $53 million remaining principal
amount of bonds at December 31,
A-34
1999, issued for similar purposes which had previously been guaranteed by TXU
Electric. TXU Electric is, however, contingently liable in the unlikely event of
default by the municipality.
Nuclear Insurance -- With regard to liability coverage, the Price-Anderson
Act (Act) provides financial protection for the public in the event of a
significant nuclear power plant incident. The Act sets the statutory limit of
public liability for a single nuclear incident currently at $9.5 billion and
requires nuclear power plant operators to provide financial protection for this
amount. As required, TXU Electric provides this financial protection for a
nuclear incident at Comanche Peak resulting in public bodily injury and property
damage through a combination of private insurance and industry-wide
retrospective payment plans. As the first layer of financial protection, TXU
Electric has purchased $200 million of liability insurance from American Nuclear
Insurers (ANI), which provides such insurance on behalf of a major stock
insurance company pool, Nuclear Energy Liability Insurance Association. The
second layer of financial protection is provided under an industry-wide
retrospective payment program called Secondary Financial Protection (SFP).
Under the SFP, each operating licensed reactor in the United States is
subject to an assessment of up to $88 million, subject to increases for
inflation every five years, in the event of a nuclear incident at any nuclear
plant in the United States. Assessments are limited to $10 million per operating
licensed reactor per year per incident. All assessments under the SFP are
subject to a 3% insurance premium tax which is not included in the amounts
above.
With respect to nuclear decontamination and property damage insurance,
Nuclear Regulatory Commission (NRC) regulations require that nuclear plant
license-holders maintain not less than $1.1 billion of such insurance and
require the proceeds thereof to be used to place a plant in a safe and stable
condition, to decontaminate it pursuant to a plan submitted to and approved by
the NRC before the proceeds can be used for plant repair or restoration or to
provide for premature decommissioning. TXU Electric maintains nuclear
decontamination and property damage insurance for Comanche Peak in the amount of
$4.0 billion, above which TXU Electric is self-insured. The primary layer of
coverage of $500 million is provided by Nuclear Electric Insurance Limited
(NEIL), a nuclear electric utility industry mutual insurance company. The
remaining coverage includes premature decommissioning coverage and is provided
by ANI in the amount of $500 million and additional insurance from NEIL in the
amount of $3.0 billion. TXU Electric is subject to a maximum annual assessment
from NEIL of $13.5 million in the event NEIL's losses under this type of
insurance for major incidents at nuclear plants participating in these programs
exceed the mutual's accumulated funds and reinsurance.
TXU Electric maintains Extra Expense Insurance through NEIL to cover the
additional costs of obtaining replacement power from another source if one or
both of the units at Comanche Peak are out of service for more than twelve weeks
as a result of covered direct physical damage. The coverage provides for weekly
payments of $3.5 million for the first fifty-two weeks and $2.8 million for the
next 110 weeks for each outage, respectively, after the initial twelve-week
period. The total maximum coverage is $490 million per unit. The coverage
amounts applicable to each unit will be reduced to 80% if both units are out of
service at the same time as a result of the same accident. Under this coverage,
TXU Electric is subject to a maximum annual assessment of $4 million per year.
Nuclear Decommissioning and Disposal of Spent Fuel -- TXU Electric has
established a reserve, charged to depreciation expense and included in
accumulated depreciation, for the decommissioning of Comanche Peak, whereby
decommissioning costs are being recovered from customers over the life of the
plant and deposited in external trust funds (included in other investments). At
December 31, 1999, such reserve totaled $167 million, which includes an accrual
of $18 million for the year ended December 31, 1999. As of December 31, 1999,
the market value of deposits in the external trust for decommissioning of
Comanche Peak was $244 million, including unrealized gains of $78 million. Any
difference between the market value of the external trust fund and the
decommissioning reserve, that represents unrealized gains or losses of the trust
fund, is treated as a regulatory asset or a regulatory liability. Realized
earnings on funds deposited in the external trust are recognized in the reserve.
Based on a site-specific study completed during 1997 using the prompt
dismantlement method and 1997 dollars, decommissioning costs for Comanche Peak
Unit 1 and for Unit 2 and common facilities were estimated to be $271 million
and $404 million, respectively.
A-35
Decommissioning activities are projected to begin in 2030 for Comanche
Peak Unit 1 and 2033 for Unit 2 and common facilities. TXU Electric is
recovering decommissioning costs based upon a 1992 site-specific study through
rates placed in effect under its January 1993 rate increase request. Actual
decommissioning costs are expected to differ from estimates due to changes in
the assumed dates of decommissioning activities, regulatory requirements,
technology and costs of labor, materials and equipment. In addition, the
marketable fixed income debt and equity securities in which assets of the
external trust are invested are subject to interest rate and equity price
sensitivity.
TXU Electric has a contract with the United States Department of Energy
(DOE) for the future disposal of spent nuclear fuel. The DOE has not begun
acceptance of spent nuclear fuel. TXU Electric's onsite spent nuclear fuel
storage capability is sufficient to accommodate the operation of Comanche Peak
through the year 2017, while fully maintaining the capability to off-load the
core of one of the nuclear-fueled generating units. Additional approval from the
NRC will be required to utilize this full storage capability. TXU Electric is
currently pursuing options for utilizing a larger portion of the full storage
capability, subject to approval by the NRC. TXU Electric is unable to predict
what impact, if any, the DOE delay will have on TXU Electric's future
operations. The disposal fee is at a cost to TXU Electric of one mill per
kilowatt-hour of Comanche Peak net generation and is included in nuclear fuel
expense.
General -- In addition to the above, TXU Electric is involved in various
other legal and administrative proceedings which the ultimate resolution, in the
opinion of management, should not have a material effect upon its financial
position, results of operations or cash flows.
15. SUPPLEMENTARY FINANCIAL INFORMATION
Sale of Receivables and Other Receivable Financing -- TXU Electric has
facilities with financial institutions whereby it is entitled to sell and such
financial institutions may purchase, on an ongoing basis, undivided interests in
customer accounts receivable representing up to an aggregate of $500 million.
Additional receivables are continually sold to replace those collected. At
December 31, 1999 and 1998, accounts receivable of TXU Electric was reduced by
$500 million and $450 million, respectively, to reflect the sales of such
receivables to financial institutions under such agreements.
Significant regulatory assets and liabilities are as follows:
December 31,
--------------------
1999 1998
---- ----
Regulatory Assets
Securities reacquisition costs........................................................ $ 431 $ 432
Recoverable redirected depreciation................................................... 146 --
Rate case costs....................................................................... 55 54
Litigation and settlement costs....................................................... 73 73
Voluntary retirement/severance program............................................... 94 90
Recoverable deferred income taxes-- net............................................... 1,558 1,623
Other regulatory assets............................................................... 63 46
------ ------
Total regulatory assets........................................................... 2,420 2,318
------ ------
Regulatory Liabilities
Liability to be applied to stranded generation assets................................. 189 --
ITC and protected excess deferred taxes............................................... 389 414
Other regulatory liabilities.......................................................... 89 69
Reserve for regulatory disallowances.................................................. 73 73
------ ------
Total regulatory liabilities...................................................... 740 556
------ ------
Net regulatory assets............................................................. $1,680 $1,762
====== ======
A-36
Affiliates -- The schedule below details TXU Electric's significant
billings to and from affiliates for services rendered and interest on short-term
financings:
Year Ended December 31,
---------------------------
1999 1998 1997
---- ---- ----
Billings from:
TXU Business Services............................................... $ 252 $ 248 $ 271
TXU Fuel............................................................ 997 1,019 996
TXU Mining.......................................................... 358 360 355
TXU SESCO........................................................... 1 1 1
Billings to:
TXU Gas............................................................. 92 107 --
TXU SESCO........................................................... 3 23 35
TXU Fuel............................................................ -- -- 1
Cash Payments -- The schedule below details TXU Electric's supplemental
cash flow information:
Year Ended December 31,
-------------------------
1999 1998 1997
---- ---- ----
Interest (net of amounts capitalized)............................... $464 $508 $537
Income taxes........................................................ 324 374 232
Quarterly Information (unaudited) -- In the opinion of TXU Electric, the
information below includes all adjustments (constituting only normal recurring
accruals) necessary for a fair statement of such amounts. Quarterly results are
not necessarily indicative of expectations for a full year's operations because
of seasonal and other factors, including rate changes, variations in maintenance
and other operating expense patterns, and the charges for regulatory
disallowances. Certain quarterly information has been reclassified to conform to
the current year presentation.
Consolidated
Operating Revenues Operating Income Net Income
------------------ ---------------- ----------
Quarter Ended 1999 1998 1999 1998 1999 1998
- ------------- ---- ---- ---- ---- ---- ----
March 31................................... $1,285 $1,332 $ 233 $ 271 $106 $ 137
June 30.................................... 1,503 1,665 290 343 162 204
September 30............................... 2,059 2,124 543 499 434 365
December 31................................ 1,360 1,367 183 220 77 92
------ ------ ------ ------ ---- -----
$6,207 $6,488 $1,249 $1,333 $779 $ 798
====== ====== ====== ====== ==== =====
16. SUBSEQUENT EVENT (Unaudited)
In October 1999, TXU Electric filed a petition with the PUC for a
financing order (Docket No. 21527) to securitize $1.65 billion of its
generation-related regulatory assets and other qualified costs in accordance
with the 1999 Restructuring Legislation. TXU Electric would issue transition
bonds securitizing a component of future revenues. The proceeds received by TXU
Electric are to be used solely for the purposes of retiring utility debt and
equity. On March 1, 2000, the PUC rejected TXU Electric's request for
securitization of the $1.65 billion and authorized securitization of only $357
million. TXU Electric believes this ruling is inconsistent with the 1999
Restructuring Legislation and announced that it will pursue an appeal to the
Travis County, Texas District Court following the receipt of a final order
evidencing such ruling from the PUC. TXU Electric expects that any difference
between the $1.65 billion and the amount finally authorized will continue to be
deferred until securitization of generation-related assets is addressed in 2002.
TXU Electric is unable to predict the outcome of these proceedings.
A-37
TXU ELECTRIC EXHIBITS FOR 1999 FORM 10-K
Appendix B
Previously Filed*
-----------------------
With
File As
Exhibits Number Exhibit
- -------- ------ -------
3(a) 0-11442 4 - Articles of Amendment, effective June 14, 1999
Form 10-Q to the Articles of Incorporation of TXU Electric.
(Quarter ended
June 30, 1999)
3(b) 0-11442 - Bylaws of TXU Electric, as restated August 1, 1999.
Form 10-Q
(Quarter ended
June 30, 1999)
4(a) 2-90185 4(a) - Mortgage and Deed of Trust, dated as of December 1, 1983,
between TXU Electric and Irving Trust Company (now The
Bank of New York), Trustee.
4(a)(1) - Supplemental Indentures to Mortgage and Deed of Trust:
Number Dated
------ -----
2-90185 4(b) First April 1, 1984
2-92738 4(a)-1 Second September 1, 1984
2-97185 4(a)-1 Third April 1, 1985
2-99940 4(a)-1 Fourth August 1, 1985
2-99940 4(a)-2 Fifth September 1, 1985
33-01774 4(a)-2 Sixth December 1, 1985
33-9583 4(a)-1 Seventh March 1, 1986
33-9583 4(a)-2 Eighth. May 1, 1986
33-11376 4(a)-1 Ninth October 1, 1986
33-11376 4(a)-2 Tenth December 1, 1986
33-11376 4(a)-3 Eleventh December 1, 1986
33-14584 4(a)-1 Twelfth February 1, 1987
33-14584 4(a)-2 Thirteenth March 1, 1987
33-14584 4(a)-3 Fourteenth April 1, 1987
33-24089 4(a)-1 Fifteenth July 1, 1987
33-24089 4(a)-2 Sixteenth September 1, 1987
33-24089 4(a)-3 Seventeenth October 1, 1987
33-24089 4(a)-4 Eighteenth March 1, 1988
33-24089 4(a)-5 Nineteenth May 1, 1988
33-30141 4(a)-1 Twentieth September 1, 1988
33-30141 4(a)-2 Twenty-first November 1, 1988
33-30141 4(a)-3 Twenty-second January 1, 1989
33-35614 4(a)-1 Twenty-third August 1, 1989
33-35614 4(a)-2 Twenty-fourth November 1, 1989
33-35614 4(a)-3 Twenty-fifth December 1, 1989
33-35614 4(a)-4 Twenty-six February 1, 1990
33-39493 4(a)-1 Twenty-seventh September 1, 1990
33-39493 4(a)-2 Twenty-eighth October 1, 1990
33-39493 4(a)-3 Twenty-ninth October 1, 1990
33-39493 4(a)-4 Thirtieth March 1, 1991
33-45104 4(a)-1 Thirty-first May 1, 1991
33-45104 4(a)-2 Thirty-second July 1, 1991
33-46293 4(a)-1 Thirty-third February 1, 1992
33-49710 4(a)-1 Thirty-fourth April 1, 1992
33-49710 4(a)-2 Thirty-fifth April 1, 1992
B-1
Previously Filed*
-------------------------
With
File As
Exhibits Number Exhibit Number Dated
- -------- ------ ------- ------ -----
33-49710 4(a)-3 Thirty-sixth June 1, 1992
33-49710 4(a)-4 Thirty-seventh June 1, 1992
33-57576 4(a)-1 Thirty-eighth August 1, 1992
33-57576 4(a)-2 Thirty-ninth October 1, 1992
33-57576 4(a)-3 Fortieth November 1, 1992
33-57576 4(a)-4 Forty-first December 1, 1992
33-60528 4(a)-1 Forty-second March 1, 1993
33-64692 4(a)-1 Forty-third April 1, 1993
33-64692 4(a)-2 Forty-fourth April 1, 1993
33-64692 4(a)-3 Forty-fifth May 1, 1993
33-68100 4(a)-1 Forty-sixth July 1, 1993
33-68100 4(a)-3 Forty-seventh October 1, 1993
33-68100 4(a)-4 Forty-eighth November 1, 1993
33-68100 4(a)-5 Forty-ninth May 1, 1994
33-68100 4(a)-6 Fiftieth May 1, 1994
33-68100 4(a)-7 Fifty-first August 1, 1994
0-11442 99 Fifty-second April 1, 1995
Form 10-Q
(Quarter ended
March 31, 1995)
0-11442 99 Fifty-third June 1, 1995
Form 10-Q
(Quarter ended
June 30, 1995)
0-11442 4 Fifty-fourth October 1, 1995
Form 8-K (Dated
September 26,
1995)
0-11442 4(a) Fifty-fifth March 1, 1996
Form 10-Q
(Quarter ended
March 31, 1996)
0-11442 4(a) Fifty-sixth September 1, 1996
Form 10-Q
(Quarter ended
September 30,
1996)
33-83976 4(g) Fifty-seventh February 1, 1997
0-11442 4(b) Fifty -eighth July 1, 1997
Form 10-Q
(Quarter ended
June 30, 1997)
4(b) - Agreement to furnish certain debt instruments.
4(c) 33-68104 4(b)-17 - Deposit Agreement between TXU Electric and Chemical Bank,
dated as of August 4, 1993.
4(d) 0-11442 4(e) - Deposit Agreement between TXU Electric and Chemical Bank,
Form 10-K dated as of October 14, 1993.
(1993)
4(e) 0-11442 4(f) - Indenture (For Unsecured Subordinated Debt Securities
Form 10-K relating to Trust Securities), dated as of December 1, 1995,
(1995) between TXU Electric and The Bank of New York, as Trustee.
B-2
Previously Filed*
------------------------
With
File As
Exhibits Number Exhibit
- -------- ------ -------
4(f) 0-11442 4(g) - Amended and Restated Trust Agreement, dated as of December
Form 10-K 12, 1995 between TXU Electric, as Depositor, and The Bank
(1995) of New York, The Bank of New York (Delaware) and the
Administrative Trustees thereunder as trustees for TXU
Electric Capital I.
4(g) 0-11442 4(h) - Guarantee Agreement with respect to TXU Electric Capital I,
Form 10-K dated as of December 12, 1995, between TU Electric, as
(1995) Guarantor, and The Bank of New York, as Trustee.
4(h) 0-11442 4(i) - Agreement as to Expenses and Liabilities, dated as of December
Form 10-K 12, 1995, between TXU Electric and TXU Electric Capital I.
(1995)
4(i) 0-11442 4(j) - Officer's Certificate, dated as of December 12, 1995,
Form 10-K establishing the terms of the Junior Subordinated Debentures
(1996) issued in connection with the preferred securities of TU
Electric Capital I.
4(j) 0-11442 4(m) - Amended and Restated Trust Agreement, dated as of December 13, 1995,
Form 10-K between TXU Electric, as Depositor, and The Bank of New York,
(1995) The Bank of New York (Delaware), and the Administrative Trustees
thereunder, as Trustees for TXU Electric Capital III.
4(k) 0-11442 4(n) - Guarantee Agreement with respect to TXU Electric Capital III,
Form 10-K dated as of December 13, 1995, between TU Electric, as
(1995) Guarantor, and The Bank of New York, as Trustee.
4(l) 0-11442 4(o) - Agreement as to Expenses and Liabilities, dated as of
Form 10-K December 13, 1995, between TU Electric and TXU Electric
(1995) Capital III.
4(m) 0-11442 4(r) - Officer's Certificate, dated as of December 13, 1995,
Form 10-K establishing the terms of the Junior Subordinated Debentures
(1996) issued in connection with the preferred securities of TXU
Electric Capital III.
4(n) 0-11442 4(s) - Amended and Restated Trust Agreement, dated as of January
Form 10-K 30, 1997, between TXU Electric, as Depositor, and The Bank
(1996) of New York (Delaware), and the Administrative Trustee as
thereunder, as Trustees for TXU Electric Capital IV.
4(o) 0-11442 4(t) - Guarantee Agreement with respect to TXU Electric Capital IV,
Form 10-K dated as of January 30, 1997, between TXU Electric, as
(1996) Guarantor and The Bank of New York, as Trustee.
4(p) 0-11442 4(u) - Agreement as to Expenses and Liabilities, dated as of January
Form 10-K 30, 1997, between TXU Electric and TXU Electric Capital IV.
(1996)
4(q) 0-11442 4(v) - Officer's Certificate, dated as of January 30, 1997, establishing
Form 10-K the terms of the Junior Subordinated Debentures issued in
(1996) connection with the preferred securities of TXU Electric Capital
IV.
4(r) 0-11442 4(w) - Amended and Restated Trust Agreement, dated as of January
Form 10-K 30, 1997, between TXU Electric, as Depositor, and The Bank
(1996) of New York (Delaware), and the Administrative Trustee
thereunder, as Trustees for TXU Electric Capital V.
4(s) 0-11442 4(x) - Guarantee Agreement with respect to TXU Electric Capital V,
Form 10-K dated as of January 30, 1997, between TXU Electric, as
(1996) Guarantor, and The Bank of New York, as Trustee.
B-3
Previously Filed*
------------------------
With
File As
Exhibits Number Exhibit
- -------- ------ -------
4(t) 0-11442 4(y) - Agreement as to Expenses and Liabilities, dated as of January
Form 10-K 30, 1997, between TXU Electric and TXU Electric Capital V.
(1996)
4(u) 0-11442 4(z) - Officer's Certificate, dated as of January 30, 1997, establishing
Form 10-K the terms of the Junior Subordinated Debentures issued in
(1996) connection with the preferred securities of TXU Electric Capital V.
4(v) 0-11442 4(a) - Indenture (For Unsecured Debt Securities), dated as of August
Form 10-Q 1, 1997, between TXU Electric and The Bank of New York.
(Quarter ended
Sept. 30, 1997)
4(w) 0-11442 4(b) - Officer's Certificate establishing the TXU Electric 7.17%
Form 10-Q Debentures due August 1, 2007.
(Quarter ended
Sept. 30, 1997)
4(x) 0-11422 99(a) - Officer's certificate establishing TXU Electric's Floating Rate
Form 10-Q debentures due April 24, 2000.
(Quarter ended
March 31, 1998)
10(a) - 364 Day Second Amended and Restated Competitive Advance
and Revolving Credit Facility Agreement, dated as of February
25, 2000 among Texas Utilities Company, TXU Electric, TXU
Gas Company, Chase Bank of Texas, National Association, as
Administrative Agent and certain banks listed therein and The
Chase Manhattan Bank, as CompetitiveAdvance Facility Agent
(US Facility A).
10(b) - Five Year Second Amended and Restated Competitive Advance
and Revolving Credit Facility Agreement dated as of
February 25, 2000 among Texas Utilities Company, TXU
Electric, TXU Gas, The Chase Manhattan Bank, as Competitive
Advance Facility Agent and Chase Bank of Texas, National
Association, as Administrative Agent and certain banks listed
therein (US Facility B).
12 - Computation of Ratio of Earnings to Fixed Charges and to
Fixed Charges and Preferred Dividends for TXU Electric.
23(a) - Consent of Counsel to TXU Electric.
23(b) - Consent of Deloitte & Touche LLP Independent Auditors' for TXU
Electric.
27 - Financial Data Schedule for TXU Electric.
99(a) 1-3591 28(b) - Agreement, dated as of February 12, 1988, between TXU
Form 10-K Electric and Texas Municipal Power Agency.
(1987)
99(b) 33-55408 99(a) - Agreement, dated as of July 5, 1988, between TXU Electric and
Electric and Tex-La Electric Cooperative of Texas, Inc.
99(c) 33-23532 4(c)(i) - Trust Indenture, Security Agreement and Mortgage, dated as of
December 1, 1987, as supplemented by Supplement No. 1
thereto dated as of May 1, 1988 among the Lessor, TXU
Electric and the Trustee.
99(d) 33-24089 4(c)-1 - Supplement No. 2 to Trust Indenture, Security Agreement and
Mortgage, dated as of August 1, 1988.
B-4
Previously Filed*
--------------------------
With
File As
Exhibits Number Exhibit
- -------- ------ -------
99(e) 33-24089 4(e)-1 - Supplement No. 3 to Trust Indenture, Security Agreement and
Mortgage, dated as of August 1, 1988.
99(f) 0-11442 99(c) - Supplement No. 4 to Trust Indenture, Security Agreement and
Form 10-Q Mortgage, including form of Secured Facility Bond, 1993
(Quarter ended Series.
June 30, 1993)
99(g) 33-23532 4(d) - Lease Agreement, dated as of December 1, 1987 between the
Lessor and TXU Electric as supplemented by Supplement No. 1
thereto dated as of May 20, 1988 between the Lessor and
TXU Electric.
99(h) 33-24089 4(f) - Lease Agreement Supplement No. 2, dated as of August 18, 1988.
99(i) 33-24089 4(f)-1 - Lease Agreement Supplement No. 3, dated as of August 25, 1988.
99(j) 33-63434 4(d)(iv) - Lease Agreement Supplement No. 4, dated as of December 1, 1988.
99(k) 33-63434 4(d)(v) - Lease Agreement Supplement No. 5, dated as of June 1, 1989.
99(l) 0-11442 99(d) - Lease Agreement Supplement No. 6, dated as of July 1, 1993.
Form 10-Q
(Quarter ended
June 30, 1993)
99(m) 33-23532 4(e) - Participation Agreement dated as of December 1, 1987, as
amended by a Consent to Amendment of the Participation
Agreement, dated as of May 20, 1988, each among the Lessor,
the Trustee, the Owner Participant, certain banking
institutions, Capcorp, Inc. and TXU Electric.
99(n) 33-24089 4(g) - Consent to Amendment of the Participation Agreement, dated
as of August 18, 1988.
99(o) 33-24089 4(g)-1 - Supplement No. 1 to the Participation Agreement, dated as of
August 18, 1988.
99(p) 33-24089 4(g)-2 - Supplement No. 2 to the Participation Agreement, dated as of
August 18, 1988.
99(q) 33-63434 4(e)(v) - Supplement No. 3 to the Participation Agreement, dated as of
December 1, 1988.
99(r) 0-11442 99(e) - Supplement No. 4 to the Participation Agreement, dated as of
Form 10-Q June 17, 1993.
(Quarter ended
June 30, 1993)
99(s) 0-11442 4(b) - Supplement No. 1, dated October 25, 1995, to Trust
Form 10-Q Indenture, Security Agreement and Mortgage, dated as of
(Quarter ended December 1, 1989, among the Owner Trustee, TXU Electric
March 31, 1996) and the Indenture Trustee.
99(t) 0-11442 4(c) - Supplement No. 1, dated October 19, 1995, to Amended and
Form 10-Q Restated Participation Agreement, dated as of November 28,
(Quarter ended 1989, among the Owner Trustee, The First National Bank of Chicago,
March 31, 1996) As Original Indenture Trustee, the Indenture Trustee, the Owner
Participant, Mesquite Power Corporation and TXU Electric.
___________________
* Incorporated herein by reference.
B-5