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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
----------------------
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended December 31, 1999 Commission File Number 1 - 6986
PUBLIC SERVICE COMPANY OF NEW MEXICO
(Exact name of Registrant as specified in its charter)
New Mexico 85-0019030
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
Alvarado Square 87158
Albuquerque, New Mexico (Zip Code)
(Address of principal executive offices)
Registrant's telephone number, including area code: (505) 241-2700
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
------------------- -----------------------------------------
Common Stock, $5.00 Par Value New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act:
(Title of Class)
--------------
1965 Series, 4.58% Cumulative Preferred Stock ($100 stated
value and without sinking fund)
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months and (2) has been subject to such filing
requirements for the past 90 days. YES |X| NO
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of 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.
The total number of shares of the Company's Common Stock outstanding as of
January 31, 2000 was 40,161,299. On such date, the aggregate market value of the
voting stock held by non-affiliates of the Company, as computed by reference to
the New York Stock Exchange composite transaction closing price of $15 7/8 per
share reported by the Wall Street Journal, was $637,560,622.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the following document are incorporated by reference into the
indicated part of this report:
Proxy Statement to be filed with the Securities and Exchange
Commission pursuant to Regulation 14A relating to the annual meeting
of stockholders to be held on June 6, 2000 - PART III.
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TABLE OF CONTENTS
Page
----
GLOSSARY................................................................ iv
PART I
ITEM 1. BUSINESS....................................................... 1
THE COMPANY................................................. 1
ELECTRIC OPERATIONS......................................... 1
Service Area and Customers.............................. 1
Power Sales............................................. 2
Sources of Power........................................ 3
Fuel and Water Supply................................... 5
NATURAL GAS OPERATIONS...................................... 8
Service Area and Customers.............................. 8
Natural Gas Supply...................................... 8
Natural Gas Sales....................................... 9
UNREGULATED OPERATIONS.....................................
DEREGULATION AND FORMATION OF HOLDING COMPANY............... 11
PROPOSED RULEMAKINGS RELATED TO DEREGULATION................ 12
COMPETITION UNDER DEREGULATION ............................. 13
RATES AND REGULATION........................................ 14
Electric Rates and Regulation........................... 14
Federal Electric Initiatives............................ 15
Gas Rates and Regulation................................ 16
ENVIRONMENTAL FACTORS....................................... 17
ITEM 2. PROPERTIES..................................................... 21
ELECTRIC.................................................. 21
Fossil-Fueled Plants.................................. 21
Nuclear Plant......................................... 22
Other Electric Properties............................. 27
NATURAL GAS............................................... 27
OTHER INFORMATION......................................... 28
ITEM 3. LEGAL PROCEEDINGS.............................................. 28
PVNGS WATER SUPPLY LITIGATION............................. 28
SAN JUAN RIVER ADJUDICATION............................... 28
OTHER PROCEEDINGS......................................... 29
Republic Savings Bank Litigation...................... 29
Purported Navajo Environmental Regulation............. 29
Nuclear Decommissioning Trust......................... 30
Royalty Claims........................................ 31
KAFB Contract......................................... 32
City of Gallup Complaint.............................. 32
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS............ 33
ii
SUPPLEMENTAL ITEM. EXECUTIVE OFFICERS OF THE COMPANY.................... 34
PART II
ITEM 5. MARKET FOR THE COMPANY'S COMMON EQUITY AND
RELATED STOCKHOLDER MATTERS............................ 36
ITEM 6. SELECTED FINANCIAL DATA...................................... 37
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS........................ 38
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT
MARKET RISK ............................................... 62
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA................. F-1
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE........................ E-1
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY.............. E-1
ITEM 11. EXECUTIVE COMPENSATION....................................... E-1
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT................................................ E-1
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS............... E-1
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K............................................... E-1
SIGNATURES.............................................................. E-21
iii
GLOSSARY
Act................................... The Clean Air Act - Amendments of 1990
Avistar............................... Avistar, Inc., an unregulated
subsidiary of Public Service Company
of New Mexico
AG.................................... New Mexico Attorney General
AMDAX................................. AMDAX.com, an equity investee of Avistar
Anaheim............................... City of Anaheim, California
APPA.................................. Arizona Power Pooling Association
APS................................... Arizona Public Service Company
BHP................................... BHP Minerals International, Inc.
BLM................................... Bureau of Land Management
BTU................................... British Thermal Unit
COA................................... City of Albuquerque, New Mexico
Decatherm............................. 1,000,000 BTUs
DOE................................... United States Department of Energy
EIP................................... Eastern Interconnection Project
El Paso............................... El Paso Electric Company
Energy................................ Manzano Energy Corporation, a proposed
subsidiary of Manzano that will
contain unregulated operations and
currently Public Service Company of
New Mexico
EPA................................... United States Environmental Protection
Agency
EPNG.................................. El Paso Natural Gas Company
FERC.................................. Federal Energy Regulatory Commission
FASB.................................. Financial Accounting Standards Board
Farmington............................ City of Farmington, New Mexico
FERC.................................. Federal Energy Regulatory Commission
FIP................................... Federal Implementation Plan
Four Corners.......................... Four Corners Power Plant
FPPCAC................................ Fuel and Purchased Power Cost
Adjustment Clause
Gallup................................ City of Gallup, New Mexico
Gathering Company..................... Sunterra Gas Gathering Company, a
wholly-owned subsidiary of Public
Service Company of New Mexico
ISO................................... Independent System Operator
KAFB.................................. Kirtland Air Force Base
Kv.................................... Kilovolt
KW.................................... Kilowatt
KWh................................... Kilowatt Hour
Los Alamos............................ The County of Los Alamos, New Mexico
mcf................................... Thousand cubic feet
Manzano............................... Manzano Corporation, the proposed
holding company of Public Service
Company of New Mexico
Meadows............................... Meadows Resources, Inc., a wholly-owned
subsidiary of Public Service Company
of New Mexico
iv
M-S-R................................. M-S-R Public Power Agency, a California
public power agency
MW.................................... Megawatt
MWh................................... Megawatt Hour
NMED.................................. New Mexico Environment Department
NMPUC................................. New Mexico Public Utility Commission
NRC................................... United States Nuclear Regulatory
Commission
OCD................................... New Mexico Oil Conservation Division
PGAC.................................. PNMGS' Purchased Gas Adjustment Clause
PLP................................... Cobisa-Person Limited Partnership
PNMGS................................. Public Service Company of New Mexico
Gas Services, a division of Public
Service Company of New Mexico
PPA................................... Power Purchase Agreement
PRC................................... New Mexico Public Regulation
Commission, predecessor of the NMPUC
Processing Company.................... Sunterra Gas Processing Company,
a wholly-owned subsidiary of Public
Service Company of New Mexico
PVNGS................................. Palo Verde Nuclear Generating Station
RCRA.................................. Resource Conservation and Recovery Act
RHC................................... Republic Holding Company
RSB................................... Republic Savings Bank
RTO................................... Regional Transmission Organization
Reeves Station........................ Reeves Generating Station
Salt River Project.................... Salt River Project Agricultural
Improvement and Power District
SCE................................... Southern California Edison Company
SCPPA................................. Southern California Public Power
Authority
SDG&E................................. San Diego Gas and Electric Company
SEC................................... Securities and Exchange Commission
SJCC.................................. San Juan Coal Company
SJGS.................................. San Juan Generating Station
SPS................................... Southwestern Public Service Company
TNP................................... Texas-New Mexico Power Company
Throughput............................ Volumes of gas delivered, whether or
not owned by PNMGS
Tri-State............................. Tri-State Generation and Transmission
Association, Inc.
Tucson................................ Tucson Electric Power Company
UAMPS................................. Utah Associated Municipal Power Systems
USBR.................................. United States Bureau of Reclamation
USEC.................................. United States Enrichment Corporation
WGA................................... Western Governors Association
WRAP.................................. Western Regional Air Partnership
Waste Act............................. Nuclear Waste Policy Act of 1982, as
amended in 1987
Western............................... Western Area Power Administration
Williams.............................. Williams Gas Processing-Blanco, Inc.,
a subsidiary of the Williams Field
Services Group, Inc., of Tulsa,
Oklahoma
v
PART I
ITEM 1. BUSINESS
THE COMPANY
Public Service Company of New Mexico (the "Company") was incorporated in
the State of New Mexico in 1917 and has its principal offices at Alvarado
Square, Albuquerque, New Mexico 87158 (telephone number 505-241-2700). The
Company is a public utility primarily engaged in the generation, transmission,
distribution and sale of electricity and in the transmission, distribution and
sale of natural gas within the State of New Mexico. In addition, in pursuing new
business opportunities, the Company is focusing on energy and utility related
services under Avistar. Avistar also operates the City of Santa Fe's water
system. (See PART II, ITEM 7. - "MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - OVERVIEW - Competitive
Strategy".)
The total population of the area served by one or more of the Company's
utility services is estimated to be approximately 1.35 million, of which 52.2%
live in the greater Albuquerque area.
For the year ended December 31, 1999, the Company derived 78.8% of its
operating revenues from electric operations, 20.4% from natural gas operations
and 0.8% from unregulated operations.
As of December 31, 1999, the Company employed 2,667 persons.
Financial information relating to amounts of revenue, net income and
total assets of the Company's reportable segments is contained in note 1 of the
notes to consolidated financial statements.
ELECTRIC OPERATIONS
Service Area and Customers
The Company's electric operations serve four principal markets. Sales to
retail customers and sales to firm-requirements wholesale customers, sometimes
referred to collectively as "system" sales, comprise two of these markets. The
third market consists of other contracted sales to utilities for which the
Company commits to deliver a specified amount of capacity (measured in MW) or
energy (measured in MWh) over a given period of time. The fourth market consists
of economy energy sales made on an hourly basis at fluctuating, spot-market
rates. Sales to the third and fourth markets are sometimes referred to
collectively as "off-system" sales.
The Company provides retail electric service to a large area of north
central New Mexico, including the cities of Albuquerque, Santa Fe, Rio Rancho,
Las Vegas, Belen and Bernalillo. The Company also provides retail electric
service to Deming in southwestern New Mexico and to Clayton in northeastern New
Mexico. As of December 31, 1999, approximately 361,000 retail electric customers
were served by the Company, the largest of which accounted for approximately
4.7% of the Company's total retail electric revenues for the year ended December
31, 1999.
1
The Company holds long-term, non-exclusive franchise agreements for its
electric retail operations, expiring between June 6, 2000, and November 2028.
These franchise agreements provide the Company access to public rights-of-way
for placement of the Company's electric facilities. The COA, City of Santa Fe,
Town of Cochiti Lake, Bernalillo County, Luna County, Sandoval County and San
Miguel County franchises have expired. Customers in the area covered by the
expired franchises represent approximately 43.2 of the Company's 1999 total
electric operating revenues, and no other franchise area represents more than
4.97%. The Company continues to collect and pay franchise fees to the COA, City
of Santa Fe and the Town of Cochiti Lake. The Company currently does not pay
franchise fees to Bernalillo County, Luna County, Sandoval County and San Miguel
County. The Company remains obligated under state law to provide service to
customers in the franchise area even in the absence of a franchise agreement.
Power Sales
For the years 1995 through 1999, retail KWh sales have grown at a
compound annual rate of approximately 3.1%. The Company's system and off-system
sales (revenues and energy consumption) and system peak demands in summer and
winter are shown in the following tables:
ELECTRIC SALES BY MARKET
(Thousands of dollars)
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Retail................................. $522,523 $536,417 $519,504 $507,821 $485,568
Firm-requirements wholesale............ $ 7,046 $ 10,708 $ 10,690 $ 12,359 $ 20,282
Other contracted off-system sales...... $226,773 $142,115 $118,876 $ 86,689 $ 43,158*
Economy energy sales................... $131,549 $122,156 $ 55,768 $ 22,281 $ 17,509*
* Due to the provision for the loss associated with the M-S-R contingent
power purchase contract recognized in 1992, revenues from other
contracted off-system sales and economy energy sales were reduced by a
total of $7.3 million in 1995.
ELECTRIC SALES BY MARKET
(Megawatt hours)
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Retail................................... 6,803,583 6,739,874 6,534,899 6,406,296 6,029,365
Firm-requirements wholesale.............. 179,249 278,615 278,727 282,534 447,629
Other contracted off-system sales........ 6,196,499 4,033,931 3,790,081 2,928,321 594,367
Economy energy sales..................... 4,795,873 4,469,769 2,716,835 1,364,365 1,548,517
SYSTEM PEAK DEMAND*
(Megawatts)
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Summer.................................. 1,291 1,313 1,209 1,217 1,247
Winter.................................. 1,161 1,135 1,142 1,111 1,076
*System peak demand relates to retail and firm-requirements wholesale
customers only.
2
The Company's wholesale power marketing area continues to increase its
trading activities. During 1999 and 1998, the Company's sales in the off-system
markets accounted for approximately 61.2% and 54.8%, respectively, of its total
KWh sales and approximately 40.3% and 32.6%, respectively, of its total revenues
from energy sales. Of the total off-system sales made in 1999, 78.0% were
transacted through purchases for resale as compared to 67.0% in 1998. However,
the Company continues to be committed to increasing its utilization of its major
generation capacity at SJGS, Four Corners and PVNGS. Capacity factors for these
generating stations were 80.0%, 71.1% and 93.2%, respectively, in 1999, as
compared to 81.8%, 87.2% and 92.5%, respectively, in 1998. During 1999, the
Company's major off-system sales contracts in effect were with SDG&E and APPA.
The SDG&E contract requires SDG&E to purchase 100 MW from the Company
through April 2001. SDG&E has filed four separate complaints with the FERC
against the Company, alleging that certain charges under the 1985 power purchase
agreement are unjust, unreasonable and unduly discriminatory. See PART II, ITEM
7. - "MANAGEMENT'S DISCUSSION AND ANAYLSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS - OTHER ISSUES FACING THE COMPANY - SAN DIEGO GAS AND ELECTRIC
("SDG&E") COMPLAINTS".
The APPA contract requires APPA to purchase varying amounts of power
from the Company through May 2008 and allows APPA to make adjustments to the
purchase amounts subject to certain notice provisions. APPA provided notice that
it was invoking its option to reduce its power demand in 1999. This resulted in
a peak demand in 1999 of 74 MW. APPA invoked the same option to reduce its peak
demand in 2000 to 68 MW.
The Company furnished firm-requirements wholesale power in New Mexico in
1999 to the City of Gallup. The Company is committed to provide service to the
City of Gallup through April 2003. Average monthly demands under the City of
Gallup contract for 1999 were approximately 27 MW. No firm-requirements
wholesale customer accounted for more than 0.8% of the Company's total electric
operating revenues for the year ended December 31, 1999.
Sources of Power
As of December 31, 1999, the total net generation capacity of facilities
owned or leased by the Company was 1,521 MW.
In addition to generation capacity, the Company purchases power in the
market. The Company has a power purchase contract with SPS which originally
provided for the purchase of up to 200 MW, expiring in May 2011. The Company may
reduce its purchases from SPS by 25 MW annually upon three years' notice. The
Company provided such notice to reduce the purchase by 25 MW in 2000 and by an
additional 25 MW in 2001. The Company has 70 MW of contingent capacity obtained
from El Paso under a transmission capacity for generation capacity trade
arrangement through 2004 and 39 MW in 2005. In addition, the Company is
interconnected with various utilities for economy interchanges and mutual
assistance in emergencies. The Company has been actively trading in the
wholesale power market and has entered into and anticipates that it will
continue to enter into power purchases to accommodate its trading activity.
3
In 1996, the Company entered into a long-term PPA with PLP to purchase
approximately 100 MW of unit contingent peaking capacity from a gas turbine
generating unit for a period of 20 years, with an option to renew for an
additional five years. In September 1997, the NMPUC approved the Company's and
PLP's applications for the project. In December 1997, PLP also received FERC
approval for "exempt wholesale generator" status with respect to the gas turbine
generating unit. In March 1998, the Company and PLP executed amendments to the
PPA and to the associated site lease and interconnection agreement, and executed
a new water use lease. The PPA was amended to change the maximum capacity the
Company was obligated to take to 132 MW and to change the commercial operation
date from May 1999 to May 2000. The gas turbine generating unit will be
constructed and operated by PLP and will be located on the Company's retired
Person Generating Station site in Albuquerque, New Mexico. The site for the
generating unit was chosen, in part, to provide needed benefits to the Company's
constrained transmission system. Primary fuel for the gas turbine generating
unit will be natural gas, which will be provided by the Company. In addition,
the unit will have the capability to utilize low sulfur fuel oil in the event
natural gas is not available.
In the September 1997 NMPUC order, the NMPUC approved the project
application and a stipulated settlement agreement ("Stipulation") which had been
entered into earlier among the Company, PLP and the NMPUC staff to resolve
certain issues raised in this proceeding. The Stipulation included, among other
things, a provision wherein the Company committed, in cooperation with the NMPUC
staff, to the development and evaluation of a request for proposal ("RFP") for
the purchase of approximately 5 MW of capacity from solar generation resources.
The Company was not obligated to build such a unit or commit to such a solar
power purchase agreement prior to the NMPUC approval of a full-cost recovery
mechanism.
By order dated October 27, 1998, the NMPUC approved the Company's
implementation of a rate rider to collect a 0.5 percent surcharge on all retail
electric bills to pay for solar and other renewable resource projects. Under the
NMPUC's order, one-half of the monies collected under the rider would have been
used to purchase or acquire resources the Company had pursued through the solar
RFP process, while the other half of the monies would have been used for other
renewable resource projects.
In November 1998, the NMPUC adopted a rule that established a "renewable
energy development program" and required New Mexico utilities to collect
voluntary contributions to a renewable energy fund from their customers. The
stated purpose of the rule was to support research, development, demonstration
and deployment of renewable energy resources. Funds collected by each utility
were to be spent by it on projects approved by the PRC based upon the
recommendations of a Renewable Energy Advisory Board appointed by the PRC. The
Company requested the PRC to exempt it from the rule on the grounds that the
rule is more than satisfied by the renewable resource program and 0.5 percent
surcharge specifically approved for the Company by the NMPUC in October 1998.
The Company's request is pending. On August 25, 1999, the PRC suspended the
proposed rule and issued an Order requiring the PRC staff to pursue a proposed
rulemaking proceeding for the purpose of amending or repealing the rule as
currently promulgated in order to conform with the requirements of the
Restructuring Act.
In addition to the long-term power purchase contract with the PLP, the
Company is pursuing other options to ensure its additional capacity needs are
met.
4
Fuel and Water Supply
The percentages of the Company's generation of electricity (on the basis
of KWh) fueled by coal, nuclear fuel and gas and oil, and the average costs to
the Company of those fuels (in cents per million BTU), during the past five
years were as follows:
Coal Nuclear Gas and Oil
-------------------- -------------------- --------------------
Percent of Average Percent of Average Percent of Average
---------- ------- ---------- ------- ---------- -------
1995...... 67.9 168.3 31.9 49.1 0.2 242.2
1996...... 68.9 159.3 30.4 49.7 0.7 238.2
1997...... 68.1 152.7 31.1 48.3 0.8 326.6
1998...... 68.2 155.3 30.8 46.5 1.0 324.6
1999...... 67.6 165.3 31.0 47.4 1.4 331.9
The estimated generation mix for 2000 is 68.2% coal, 30.1% nuclear and
1.7% gas and oil. Due to locally available natural gas and oil supplies, the
utilization of locally available coal deposits and the generally abundant supply
of nuclear fuel, the Company believes that adequate sources of fuel are
available for its generating stations.
Coal
The coal requirements for the SJGS are being supplied by SJCC, a
wholly-owned subsidiary of BHP, from certain Federal, state and private coal
leases under a Coal Sales Agreement, pursuant to which SJCC will supply
processed coal for operation of the SJGS until 2017. BHP guaranteed the
obligations of SJCC under the agreement, which contemplates the delivery of
approximately 94 million tons of coal during its remaining term. Such amount
would supply substantially all the requirements of the SJGS through
approximately 2017. The primary sources of coal for current operations are a
mine adjacent to the SJGS and a mine located approximately 25 miles northeast of
the SJGS in the La Plata area of northwestern New Mexico. The Coal Sales
Agreement contemplated that additional coal resources would be required during
the remaining term of the agreement. The Company is currently in discussions
with SJCC regarding alternatives for coal resource selection. For other
information related to coal requirements, see PART II, ITEM 7. - "MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - OTHER
ISSUES FACING THE COMPANY - COAL FUEL SUPPLY".
Four Corners is supplied with coal under a fuel agreement between the
owners and BHP, under which BHP agreed to supply all the coal requirements for
the life of the plant. BHP holds a long-term coal mining lease, with options for
renewal, from the Navajo Nation and operates a surface mine adjacent to Four
Corners with the coal supply expected to be sufficient to supply the units for
their estimated useful lives.
5
Natural Gas
The natural gas used as fuel for the Company's Albuquerque electric
generating plant (Reeves Station) is delivered by PNMGS. (See "NATURAL GAS
OPERATIONS".) In addition to rate changes under filed tariffs, the Company's
cost of gas increases or decreases according to the average cost of the
available gas supply.
Nuclear Fuel
The fuel cycle for PVNGS is comprised of the following stages:
o The mining and milling of uranium ore to produce uranium concentrates,
o The conversion of uranium concentrates to uranium hexafluoride,
o The enrichment of uranium hexafluoride,
o The fabrication of fuel assemblies,
o The utilization of fuel assemblies in reactors and
o The storage of spent fuel and the disposal thereof.
The PVNGS participants have made contractual arrangements to obtain
quantities of uranium concentrates anticipated to be sufficient to meet
operational requirements through 2002. Existing contracts and options could be
utilized to meet approximately 88% of requirements in 2003, 88% of requirements
in 2004, 49% of requirements in 2005, and 16% of requirements from 2006 and
beyond. Spot purchases on the uranium market will be made, as appropriate, in
lieu of any uranium that might be obtained through contractual options.
The PVNGS participants have contracted for uranium conversion services.
Existing contracts and options could be utilized to meet approximately 70% of
requirements in 2000, 75% of requirements in 2001 and 80% of requirements in
2002. The PVNGS participants have an enrichment services contract and an
enriched uranium product contract that furnish enrichment services required for
the operation of the three PVNGS units through 2015. In addition, existing
contracts will provide fuel assembly fabrication services until at least 2003
for each PVNGS unit.
Water Supply
Water for Four Corners and SJGS is obtained from the San Juan River.
(See ITEM 3. - "LEGAL PROCEEDINGS - SAN JUAN RIVER ADJUDICATION".) BHP holds
rights to San Juan River water and committed a portion of such rights to Four
Corners through the life of the project. The Company and Tucson have a contract
with the USBR ("USBR Contract") for consumption of 16,200 acre feet of water per
year for the SJGS, which contract expires in 2005, and in addition, the Company
was granted the authority to consume 8,000 acre feet of water per year under a
state permit that is held by BHP. The Company is of the opinion that sufficient
water is under contract for the SJGS through 2005.
In January 1993, the U.S. Fish and Wildlife Service proposed a portion
of the San Juan River as critical habitat for two fish species. This designation
may impact uses of the river and its flood plains and will require certain
analysis under the Endangered Species Act of 1973 of all significant Federal
actions. Renewal of the SJGS water contract is considered a significant Federal
action.
6
Due to extensive lead times required to renew the water rights contract,
the Company formally initiated the renewal and extension process for requesting
rights through the year 2025. The Company is actively conducting an
environmental assessment with the USBR and a biological assessment with the U.S.
Fish and Wildlife Service. These studies are required by the Federal agencies
before the existing water contract can be renewed.
In June 1996, the Navajo Nation requested that the USBR withhold renewal
of the USBR Contract due to water shortages of the Navajo Indian Irrigation
Project. Other tribes in the Four Corners area also voiced concern to the USBR
about the renewal by the Company of the USBR Contract. Due to the tribal
concerns expressed, the Company began four-way discussions with the Jicarilla
Apache Tribe ("Jicarilla"), the Navajo Nation, and USBR in July 1999 to resolve
any outstanding issues related to the Company's proposed renewal of the USBR
Contract. Those discussions are ongoing but have resulted in the Company
pursuing an alternative water supply to replace the USBR Contract when it
expires in 2005.
Currently, the Company is in discussions with Jicarilla for a
twenty-seven year contract, beginning in 2006, for the full 16,200 AF of water
from the Jicarilla supply in Navajo Reservoir ("Jicarilla Contract"). The
Jicarilla Contract is proposed to be essentially equivalent to a renewed USBR
Contract, the only material difference being that Jicarilla as opposed to USBR
would be the contract supplier. Jicarilla has contract water in Navajo Reservoir
pursuant to a water rights settlement approved by Congress in 1992 and judicial
decree that was entered February 24, 1999. Unlike a renewed USBR Contract, the
Company would not be required to seek Congressional approval of a Jicarilla
Contract.
Additionally, the Company is in discussion with the Navajo Nation to
settle claims the tribe may assert in connection with any environmental
approvals that may be required for a Jicarilla Contract. The Jicarilla Contract
is considered a Federal action that will require National Environmental Policy
Act compliance as well as a Section 7 consultation under the Endangered Species
Act. At this time, although the Company cannot predict the outcome of these
discussions, it does not believe that a settlement with the Navajo Nation will
have a material impact on the Company or its operations.
The Company is actively involved in the San Juan River Recovery
Implementation Program ("Recovery Program") to mitigate any concerns with the
taking of the USBR Contract or proposed Jicarilla Contract water supply from a
river that contains endangered fish species and their critical habitat. In April
of 1999, the Recovery Program voted to fund modifications to the Company's weir
to accommodate fish travel in that area of the river. Funding is expected to be
supplied by USBR. Design studies are ongoing and the project is expected to
commence in 2001.
Sewage effluent used for cooling purposes in the operation of the PVNGS
units is obtained under contracts with certain municipalities in the area. The
contracted quantity of effluent exceeds the amount required for the three PVNGS
units. The validity of these effluent contracts is the subject of litigation in
state court. (See ITEM 3. - "LEGAL PROCEEDINGS - PVNGS WATER SUPPLY
LITIGATION".)
7
NATURAL GAS OPERATIONS
Service Area and Customers
The Company's gas operating division, PNMGS, distributes natural gas to
most of the major communities in New Mexico, including Albuquerque and Santa Fe,
serving approximately 426,000 customers as of December 31, 1999. The Albuquerque
metropolitan area accounts for approximately 51.7% of the total sales-service
customers. PNMGS holds long-term, non-exclusive franchises with varying
expiration dates in all incorporated communities requiring franchise agreements
except for the COA, which expired on January 28, 1998. PNMGS' customer base
includes both sales-service customers and transportation-service customers.
Sales-service customers purchase natural gas and receive transportation and
delivery services from PNMGS for which PNMGS receives both cost-of-gas and
cost-of-service revenues. Cost-of-gas revenues collected from on-system
sales-service customers are recovered in accordance with PRC rules and
regulations and do not affect the net earnings of the Company. Additionally,
PNMGS makes occasional gas sales to off-system customers. Off-system sales
deliveries generally occur at interstate pipeline interconnects with PNMGS'
system. Transportation-service customers, who procure gas independently of PNMGS
and contract with PNMGS for transportation and related services, provide PNMGS
with cost-of-service revenues only. Transportation services are provided to gas
marketers, producers and end users for delivery to locations throughout the
PNMGS distribution systems, as well as for delivery to interstate pipelines.
PNMGS provided gas transportation deliveries to approximately 1,244 gas
marketers, producers and end users during 1999.
For the twelve months ended December 31, 1999, PNMGS had throughput of
approximately 92.3 million decatherms, including sales of 52.1 million
decatherms to both sales-service customers and off-system customers. No single
sales-service customer accounted for more than 4.2% of PNMGS' therm sales in
1999. During 1999, approximately 43.6% of the PNMGS' total gas throughput was
related to transportation gas deliveries. PNMGS' transportation rates are
unbundled, and transportation customers only pay for the service they receive.
PNMGS' total operating revenues for the year ended December 31, 1999, were
approximately $236.7 million. Cost-of-gas revenues, received from sales-service
and off-system customers, accounted for approximately 47.7% of PNMGS' total
operating revenues. Since a major portion of PNMGS' load is related to heating,
levels of therm sales are affected by weather. Approximately 43.3% of PNMGS'
total therm sales in 1999 occurred in the months of January, February, November
and December.
Natural Gas Supply
PNMGS obtains its supply of natural gas primarily from sources within
New Mexico pursuant to contracts with producers and marketers. These contracts
are generally sufficient to meet PNMGS' peak-day demand. PNMGS serves certain
cities which depend on EPNG or Transwestern Pipeline Company for transportation
of gas supplies. Because these cities are not directly connected to PNMGS
transmission facilities, gas transported by these companies is the sole supply
source for those cities. Such transportation is regulated by FERC. As a result
of FERC Order 636, PNMGS' options for transporting gas to such cities and other
portions of its distribution system have increased.
8
Natural Gas Sales
The following table shows gas throughput by customer class*:
GAS THROUGHPUT
(Millions of decatherms)
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Residential.............. 29.3 30.3 30.7 27.4 25.9
Commercial............... 10.1 10.4 10.6 9.3 8.9
Industrial............... 2.3 1.5 1.3 2.1 0.7
Public authorities....... 2.9 3.4 4.2 2.6 2.4
Irrigation............... 1.4 1.9 1.6 1.4 1.2
Sales for resale......... 1.2 1.2 1.2 0.8 1.3
Unbilled................. 3.8 (1.3) (0.2) 1.4 (1.8)
Transportation**......... 40.2 36.4 34.0 47.1 69.8
Off-system sales......... 1.1 1.9 1.2 8.0 1.2
---- ---- ---- ----- -----
92.3 85.7 84.6 100.1 109.6
==== ==== ==== ===== =====
The following table shows gas revenues by customer class*:
GAS REVENUES
(Thousands of dollars)
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Residential............... $148,968 $161,153 $187,563 $129,911 $125,290
Commercial................ 36,528 42,680 50,502 33,022 32,328
Industrial................ 8,550 4,887 4,536 5,179 1,873
Public authorities........ 9,782 12,610 17,577 8,018 7,939
Irrigation................ 4,229 5,780 5,041 3,252 3,077
Sales for resale.......... 2,530 3,596 4,465 2,106 3,114
Unbilled.................. 4,107 (955) (2,172) 2,678 (2,430)
Transportation**.......... 12,390 13,464 14,172 17,215 22,172
Liquids................... 1,867 1,463 4,451 7,608 13,414
Processing fees........... - - - - 5,180
Off-system sales.......... 2,357 3,816 1,926 14,352 1,927
Other..................... 5,403 7,481 6,708 3,960 4,101
-------- -------- -------- -------- --------
$236,711 $255,975 $294,769 $227,301 $217,985
======== ======== ======== ======== ========
* On June 30, 1995, the Company sold substantially all of the gas gathering
and processing assets of the Company and its gas subsidiaries. The above
information reflects the revenues and throughput of the gathering company
and processing company through this date.
** Customer-owned gas.
9
UNREGULATED OPERATIONS
The Company, through its wholly-owned subsidiary Avistar, has initiated
several unregulated service and information business lines to serve energy
intensive customers. The Avistar business lines consist of Energy Partners,
Pathways Integration and Phaser Advanced Metering Services. Energy Partners
provides energy management solutions that assist customers in implementing cost
effective procurement, distribution and consumption of energy. Pathways
Integration is seeking opportunities in infrastructure and energy management
with a specific focus on the municipal and Native American markets. Avistar
currently has a contract with the City of Santa Fe to operate the Santa Fe water
system through mid-2001. Phaser Advanced Metering Services provides electric
meter installation, testing service and consulting expertise to energy service
providers as well as commercial and industrial customers. On August 4, 1998, the
Company adopted a plan to discontinue the natural gas trading operations of its
Energy Marketing business segment of the Energy Services Business Unit. (See
PART II, ITEM 7. - "MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS - RESULTS OF OPERATIONS - Discontinued Operations".)
In June 1999, the NMPUC issued a final order approving the Company's
request to form and invest in a wholly-owned subsidiary, Avistar. Under the
final order, the Company is permitted to invest a maximum of $50 million in the
subsidiary, subject to the availability of the Company's retained earnings and
to enter into reciprocal loan agreement for up to $30 million. While the
terminology of "available unappropriated retained earnings" quoted in the order
is subject to interpretation, the Company believes it currently has sufficient
retained earnings to make the investments.
Avistar commenced operations starting on August 11, 1999. The business
lines now contained in Avistar were operated in the Energy Services Business
Unit of the Company prior to the formation and funding of Avistar. Since its
inception, Avistar has entered into an exclusive license arrangement with Sandia
Corporation in October 1999, to modify and market a reliability and predictive
maintenance software suite. The Company anticipates marketing this product to
utilities, manufacturers and a variety of other industry segments concerned
about optimizing operational performance.
Avistar has also acquired approximately 25% ownership interest in
AMDAX.com, a developer of an internet-based energy exchange, by agreement dated
January 24, 2000. AMDAX has developed a proprietary, auction platform designed
to efficiently bring together electricity buyers and sellers in the deregulated
natural gas and electricity markets. Avistar has also entered into an agreement
with AMDAX to provide metering, regulatory and information systems support to
AMDAX.
DEREGULATION AND FORMATION OF HOLDING COMPANY
Introduction of competitive market forces and restructuring of the
electric utility industry in New Mexico continue to be key issues facing the
Company. The Electric Utility Industry Restructuring Act of 1999 (the
"Restructuring Act"), was enacted into law on April 8, 1999, opening the state's
electric power market to customer choice beginning in 2001. The law gives
schools, residential and small business customers the opportunity to choose
among competing power suppliers beginning in January 2001. Competition will be
expanded to include all customers starting in January 2002. The PRC, however,
can extend these dates by up to one year if necessary. Rural electric
cooperatives and municipal electric systems have the option not to participate
in the competitive market.
10
Residential and small business customers who do not select a power
supplier in the open market can buy their electricity through their local
utility through a "standard offer" whereby the local distribution utility will
purchase power supplies through a competitive process approved by the PRC. The
local distribution utility system and related services such as billing and
metering will continue to be regulated by the PRC, while the interstate
transmission system will remain subject to Federal regulation.
The law does not require utilities to divest their generating plants,
but requires unregulated activities to be separated from the regulated
activities through creation of at least two separate corporations.
The Company is required to file a transition plan with the PRC by June
1, 2000. The transition plan must include proposals for: (i) implementing
customer choice and open access to the Company's transmission and distribution
system; (ii) separating regulated and non-regulated business activities; (iii)
recommended rates for distribution, transmission and related services; (iv)
competitive procurement process for standard offer; and (v) the recovery of
stranded costs and transition costs. The Company plans to reorganize its
operations by forming a holding company structure as a means of achieving the
corporate and asset separation required by the Restructuring Act. The holding
company, which was incorporated in March 2000, as a minimally capitalized
wholly-owned subsidiary, has been named Manzano Corporation.
Under the Company's restructuring plan, all of the outstanding shares of
the Company's common stock will be exchanged on a share-for-share basis for
shares of Manzano common stock. Thus, when the share exchange is completed, each
shareholder of the Company's common stock immediately prior to the share
exchange will own the same number of shares (and percentage) of Manzano common
stock. Likewise, Manzano will own all of the outstanding shares of the Company's
common stock. If the share exchange is implemented, shareholders will not be
required to surrender their existing stock certificates for stock certificates
of Manzano.
If the shareholders approve the agreement and plan of share exchange,
and if the applicable regulatory approvals are obtained and other conditions are
satisfied, the share exchange will become effective upon the filing of the
Articles of Exchange relating to the share exchange with the Corporations Bureau
of the PRC. The share exchange proposal requires the affirmative vote of the
holders of two-thirds of the shares of the Company's common stock entitled to
vote at the annual meeting.
If the Company receives all necessary regulatory and other approvals,
pursuant to the Restructuring Act, all of the Company's electric and gas
distribution and transmission assets and related liabilities will be transferred
to a newly created subsidiary after completion of the share exchange. After this
asset transfer, this subsidiary will acquire the name "Public Service Company of
New Mexico" (for purposes of this discussion, the subsidiary will be referred to
as "UtilityCo") and the corporation formerly named Public Service Company of New
Mexico will be renamed Manzano Energy Corporation. Energy will continue to own
the Company's existing electric generation and unregulated, competitive assets
after completion of the transfer of the regulated business to the newly created
utility subsidiary. Shareholder approval is not required for the asset and
liability transfer to UtilityCo, which will occur after the completion of the
share exchange if the Company receives all necessary approvals. UtilityCo and
Energy will be wholly-owned subsidiaries of Manzano.
11
The share exchange itself will not result in any change in the
outstanding indebtedness of the Company. In addition, the Company's preferred
stock will remain an equity security of Energy after the share exchange unless
an exchange offer for the preferred stock is made by UtilityCo and accepted by
all the holders or the preferred stock is redeemed by the Company.
The Company is filing its transition plan with the PRC pursuant to the
Restructuring Act in three parts. In November 1999, the Company filed the first
two parts of the transition plan with the PRC. Part one requested approval by
February 1, 2000 to create Manzano and UtilityCo as wholly-owned shell
subsidiaries of the Company. In response to this request, the Company received
an order from the PRC on February 15, 2000 authorizing it to form Manzano and
UtilityCo as wholly-owned shell subsidiaries of the Company. Part two of the
transition plan requested, by June 1, 2000, all PRC approvals necessary for the
Company to implement the formation of the holding company structure and the
share exchange and its separation plan pursuant to the Restructuring Act.
However, the part two hearing was scheduled for May 15, 2000 which will make a
June 1, 2000 approval unlikely. Therefore, the Company has assumed a July 1,
2000 approval date with an August 1, 2000 separation date. PRC staff filed a
motion in February 2000 to delay the May 15, 2000 hearing date. The Company
filed a motion in opposition in February 2000. As discussed, this separation
plan involves the transfer of the regulated business of the Company (generally,
electric and gas distribution and transmission assets) to UtilityCo so Energy
will maintain ownership of the competitive, deregulated businesses (generally,
generation and related assets). This transfer is expected to take place after
the consummation of the share exchange assuming the receipt of all necessary
regulatory and other approvals. Part three of the Company's transition plan will
address transition costs, stranded costs, UtilityCo's cost of service, standard
offer service and other issues required to be considered under the Restructuring
Act.
The Company expects to file a Form S-4 Registration Statement for the
share exchange discussed above with the Securities and Exchange Commission
subsequent to the filing of this Form 10-K. The Form S-4 will provide additional
detail on the proposed share exchange.
PROPOSED RULEMAKINGS RELATED TO DEREGULATION
Code of Conduct
On August 17, 1999, the PRC issued a notice of proposed rulemaking
seeking comments on a Code of Conduct rule. The stated purpose of the proposed
Code of Conduct rule is to establish procedures governing public utilities and
the relationship and interactions between a public utility and an affiliate that
has been licensed by the Commission to provide retail competitive power supply
and energy related services as required by the Restructuring Act. The PRC has
not finalized its proposed rule.
12
Standard Offer Service Rule
On August 17, 1999 the PRC issued a notice of proposed rulemaking
seeking comments on a Standard Offer Service rule. The stated purpose of the
proposed Standard Offer Service rule is to establish procedures governing
utilities regarding the terms and conditions for acquisition and service by a
public utility of generation service for standard offer service as required by
the Restructuring Act (see PART II. - ITEM 7. "MANAGEMENT'S DISCUSSION AND
ANALYSIS AND RESULTS OF OPERATIONS - OVERVIEW - Restructuring the Electric
Industry"). Numerous parties, including the Company, submitted comments on the
proposed rule. Hearings were held on November 17, 1999. On January 18, 2000, PRC
Staff filed its proposed final Standard Offer Service rule. The PRC has not yet
issued the final Standard Offer Service rule.
Customer Protection Rule
On September 21, 1999 the PRC issued a notice of proposed rulemaking
seeking comments on a Customer Protection rule. The stated purpose of the
proposed Customer Protection rule is to carry out the requirements of the
Restructuring Act to protect New Mexico electric service customers by providing
for: 1) customer change of competitive power suppliers and authorization of
service; 2) fair and reasonable marketing, sales, and billing practices,
including truthful advertising and disclosure practices; and 3) an expeditious
procedure for resolving disputes between customers and competitive power
suppliers regarding compliance with this rule. Numerous parties, including the
Company submitted comments on the proposed rule. Hearings were held on January
11, 2000. On January 18, 2000, PRC Staff filed its proposed final customer
protection rule. Additional hearings will be held on March 22, 2000. The PRC has
not yet issued the final Customer Protection rule.
COMPETITION UNDER DEREGULATION
Under current law, the Company is not in any direct retail competition
with any other regulated electric and gas utility. Nevertheless, the Company is
subject to varying degrees of competition in certain territories adjacent to or
within areas it serves that are also currently served by other utilities in its
region as well as cooperatives, municipalities, electric districts and similar
types of government organizations.
The Restructuring Act in New Mexico, which was enacted into law on April
8, 1999, opened the state's electric power market to customer choice for certain
customers beginning in 2001 and the balance of customers in 2002. These dates
can be extended by one year under the law. As a result, the Company may face
competition from companies with greater financial and other resources. There can
be no assurance that the Company will not face competition in the future that
would adversely affect its results.
It is the current intention to have the Company's competitive
subsidiaries, including Avistar, engage primarily in energy-related businesses
that will not be regulated by state or Federal agencies that currently regulate
public utilities (other than the FERC and NRC). These competitive businesses,
including the generation business, will encounter competition and other factors
not previously experienced by the Company, and may have different, and perhaps
greater, investment risks than those involved in the regulated business.
Specifically, the passage of the Restructuring Act and deregulation in the
electric utility industry generally are likely to have a significant impact on
the price and margins for electric generation and thus, the recovery of the
investment in electric generation assets. In response to competition and the
need to gain economies of scale, electricity producers will need to control
13
costs to maintain margins, profitability and cash flow that will be adequate to
support investments in new technology and infrastructure. The Company's current
business plan includes a 300% increase in sales and a doubling of its generating
capacity through the construction or acquisition of additional power generation
assets in its surrounding region of operations. Such growth will be dependent
upon the Company's ability to generate $400 to $600 million to fund the
Company's expansion. There can be no assurance that these competitive
businesses, particularly the generation business, will be successful or, if
unsuccessful, that they will not have a direct or indirect adverse effect on the
Company.
The Company's ability to obtain funds to invest in its competitive
businesses depends upon recovery of stranded costs, borrowings and other
financings, and any issuances of common or preferred stock.
RATES AND REGULATION
The Company is subject to the jurisdiction of the PRC, the successor of
the NMPUC effective January 1, 1999, with respect to its retail electric and gas
rates, service, accounting, issuance of securities, construction of major new
generation and transmission facilities and other matters. The FERC has
jurisdiction over rates and other matters related to wholesale electric sales.
Electric Rates and Regulation
Electric Rate Case
In November 1998, the NMPUC issued a final order in the Company's
electric rate case, requiring the Company to reduce rates in 1999 by $60.2
million, by $25.6 million in 2000 and by an additional $25.6 million in 2001.
The rate reduction order reflected, among other things, the revaluation of the
Company's generation resources based on a so-called "market-based price" and the
finding by the NMPUC that recovery of stranded costs is illegal. In December
1998, the Company appealed the rate case order to the New Mexico Supreme Court
("Supreme Court").
On March 15, 1999, the Supreme Court issued a ruling, vacating the NMPUC
order on the Company's electric rate case and remanding the case to the PRC, the
successor of the NMPUC, for further proceedings.
On August 25, 1999, the PRC issued an order approving a settlement. The
PRC ordered the Company to reduce its electric rates by $34.0 million
retroactive to July 30, 1999. In addition, the order includes a rate freeze
until retail electric competition is fully implemented in New Mexico or until
January 1, 2003. The settlement will reduce annual revenues by an estimated
$37.0 million based on expected customer growth and will reduce electric
distribution operating revenues in the year 2000 by approximately $20 million.
14
As part of the settlement, the Company agreed that certain language
changes to the tariff KAFB currently takes service under be set for a separate
hearing before the PRC. Hearings on this issue have not yet been scheduled. KAFB
has not renewed its power service contract with the Company that expired in
December 1999 (see ITEM 3. - "LEGAL PROCEEDINGS - OTHER PROCEEDINGS - Kirtland
Air Force Base ("KAFB") Contract").
Net Metering Rule
In September 1998, the NMPUC issued a notice of proposed rulemaking
seeking comments on a Net Metering rule. "Net metering" refers to the
measurement of the difference between the electricity that is supplied by a
utility and the electricity that is generated by a customer's generator and fed
back into the utility's system. The stated purpose of the proposed net metering
rule was to actively promote the use of small-scale, customer-owned and other
renewable energy resources, distributed generation and alternative technology
energy resources and facilities. Comments on the proposed rule were submitted by
numerous parties, including the Company. After additional comments were filed
and a hearing held on April 19, 1999 the PRC promulgated the Net Metering rule
by final order dated September 7, 1999. The Net Metering rule is (1) limited to
facilities less than 10 kW; (2) applicable only to qualifying facilities; and
(3) provides for interconnection of customer-owned generation by qualifying
facilities with only a single bi-directional meter with no payment for excess
generation or demand credits.
Federal Electric Initiatives
Beginning with the passage of the Public Utility Regulatory Policies Act
of 1978 and, subsequently, the Energy Policy Act, there has been a significant
increase in the level of competition in the market for the generation and sale
of electricity. The Energy Policy Act reduced barriers to market entry for
companies wishing to build, own and operate electric generating facilities, and
it also promoted competition by authorizing the FERC to require transmission
service for wholesale power transactions. In this regard, in 1996, the FERC
issued Order 888. Among other things, Order 888 required electric utilities
controlling transmission facilities to file open access transmission tariffs
that would make the utility transmission systems available to wholesale sellers
and buyers of electric energy on a non-discriminatory basis.
Order 888 encouraged utilities to investigate the formation of
independent system operators, or ISOs, to operate transmission assets and
provided criteria under which the formation, operation and governance of ISOs
would be reviewed. On December 20, 1999, the FERC issued its Order 2000 on RTOs.
In this order, the FERC established timelines for transmission owning entities
to join an RTO and defined the minimum characteristics and functions that an RTO
must satisfy.
In January 1998, the Company entered into a development agreement with
other transmission service providers and users to form an ISO in the southwest.
The development agreement called for the development of the ISO to be separated
into two phases. The first phase defined the operating, pricing, planning and
legal parameters of the ISO. The second phase, still underway, was to develop
the by-laws, articles of incorporation and various tariffs and agreements
required.
15
Desert STAR, Inc. was incorporated as a non-profit organization in the
State of Arizona on September 21, 1999. Desert STAR, Inc. is being developed to
satisfy the FERC functions and characteristics for an approved RTO. The
functions of Desert STAR RTO are envisioned to include the following: (1) tariff
administration and design; (2) congestion management; (3) parallel flow
internalization; (4) ancillary services; (5) OASIS management and total
transmission capability and available transmission capability estimation; (6)
market monitoring; (7) planning and expansion; and (8) inter-regional
coordination.
The Company is currently unable to predict the ultimate timing of the
formation or the ultimate outcome of the proposed Desert STAR RTO.
Gas Rates and Regulation
The 1995 Gas Rate Case Appeal
In 1995, the Company filed a request for a $13.3 million increase in its
retail natural gas sales and transportation rates. On February 13, 1997, the
NMPUC issued a final order in the gas rate case, ordering a rate decrease of
approximately $6.9 million. The Company filed an appeal to the Supreme Court
from the NMPUC's final order. The Company is awaiting a decision by the Supreme
Court, but is unable to predict the timing or the ultimate outcome. While the
appeal is pending, the NMPUC's final order remains in effect.
The 1997 Gas Rate Case
In October 1997, the Company filed a gas rate case in compliance with a
NMPUC order. In April 1998, an uncontested stipulation settling the 1997 gas
rate case was filed with the NMPUC. After a hearing on the stipulation held in
May 1998, the NMPUC issued a final order in August 1998, accepting the
stipulation with certain modifications. The order approved a program under which
customers could choose between two cost of service rate options (either a $9.00
monthly fee with a higher volumetric cost of service charge or a $14.56 monthly
fee with a lower volumetric cost of service charge). This option program became
effective with the December 1998 billing cycle. Subsequent to the NMPUC's denial
of the AG's request for rehearing, the AG appealed the order to the Supreme
Court in October 1998. However, the AG did not request a stay and therefore the
NMPUC's order remains in effect while the appeal is pending.
PGAC Continuation Filing
The Company's retail gas rate tariffs contain a PGAC that provides
timely recovery for the cost of gas purchased for resale to its sales-service
customers. In a NMPUC order issued November 1997, the Company was required to
file its next PGAC continuation filing no later than November 23, 1999. In
November 1999, the Company requested a variance to the filing requirement, which
was granted by the PRC that deferred the filing until the issuance of a final
order in either of two related cases concerning an investigation into the
Company's gas hedging practices (see "Gas Hedging Investigation" below) and a
notice of proposed rulemaking issued by the PRC that would rewrite the PGAC rule
(see "PRC PGAC Rule Rewrite" below).
16
Gas Hedging Investigation
In response to a July 1999 request from the PRC staff, the Company
provided information that included the costs for both financial and physical
hedges and physical transactions entered into for the winter of 1998-1999 to
levelize gas costs and protect against price spikes. The total cost was $7.6
million; about 7.5% of total annual purchased gas costs. The PRC staff and the
AG filed a petition in May 1999, requesting a review of the Company's gas
hedging program and that the PRC consider whether specific guidelines should be
established. On August 13, 1999, the Company, staff and the AG jointly filed a
proposal as to the scope for the proceeding and suggested that the Company file
a white paper on its hedging practices. The hearing examiner adopted this
proposal and on October 16, 1999, the Company filed a report on the history of
the PRC's actions, the results of the Company's hedging activities, and a review
of industry hedging practices. The heart of the case centers on an order from
the former NMPUC, in the 1997 PGAC prudence case, in which the Company was
ordered to engage in gas hedging in an effort to levelize and/or stabilize gas
prices without detailing guidelines under which to do so. The current case
appears to be heading in the direction of allowing the Company to hedge without
ordering it to do so and providing general guidelines. A two-day workshop was
held in early February 2000, and a hearing date is scheduled for March 27, 2000.
PRC PGAC Rule Rewrite
Throughout 1999 and continuing through the present, the Company has
worked in a cooperative effort with the Commission staff, the AG, Zia Natural
Gas and Raton Natural Gas to develop a proposed revision to the PRC PGAC rule. A
joint filing was made proposing a new PGAC rule on September 30, 1999. The AG
declined to sign the filing and filed an opposition to the petition for
rulemaking due to the group's removal of the phrase "lowest reasonable cost"
from the proposed PGAC rule. On October 19, 1999, the Commission issued a notice
of proposed rulemaking to address the issue of rewriting the PRC's PGAC rule.
Following a pre-hearing conference, the PRC issued a notice of further
rulemaking in mid November 1999, that directed the parties to file comments in
the case and to comment on the AG's filed opposition. The Company, Staff and Zia
filed comments in support of the proposed rule with minor wording changes to the
proposed rule and general comments regarding the AG's filed opposition in
December 1999. All parties, including the AG, are in agreement to include the
phrase "lowest reasonable cost" in the proposed rule so long as that phrase is
adequately defined, providing clear direction to the gas utilities in their gas
cost recovery efforts. Should this rule be adopted as proposed, the requirement
that gas utilities make a biannual PGAC continuation filing would be replaced
with a more timely and informative annual supply and demand forecast, planning,
true-up reporting process, and a simplified PGAC continuation filing every four
years. A hearing was held February 1, 2000 on this rulemaking. A workshop to
discuss minor proposed rule revisions has been scheduled for March 27, 2000.
ENVIRONMENTAL MATTERS
The Company, in common with other electric and gas utilities, is subject
to stringent laws and regulations for protection of the environment by local,
state, Federal and tribal authorities. In addition, PVNGS is subject to the
jurisdiction of the NRC, which has authority to issue permits and licenses and
to regulate nuclear facilities in order to protect the health and safety of the
public from radioactive hazards and to conduct environmental reviews pursuant to
the National Environmental Policy Act. Liabilities under these laws and
regulations can be material and, in some instances, may be imposed without
regard to fault, or may be imposed for past acts, even though such acts may have
been lawful at the time they occurred.
17
The Clean Air Act
The 1990 amendments to the Clean Air Act established the acid rain
program which addresses SO2 and NOx emissions from fossil-fired power plants.
All of the Company's power plants that are subject to the acid rain rules are
Phase II units. Phase II of the acid rain program became effective on January 1,
2000.
Due to the existing air pollution control equipment on the coal-fired
SJGS and Four Corners, the Company will not be faced with any material capital
expenditures in order to comply with the acid rain provisions for sulfur dioxide
and nitrogen dioxide. Under Title V of the Act, the Company is required to
obtain operating permits for its coal- and gas-fired generating units and to pay
annual fees associated with the operating permit program. The New Mexico
operating permit program was approved by the EPA in November 1994. The Company
received operating permits for SJGS and Reeves Station in August 1998 and March
1998, respectively.
On July 1, 1999, the EPA published the final regional haze regulations.
The purpose of the regional haze regulations is to address regional haze
visibility impairment in the 156 Class 1 areas in the nation. The final rule
calls for all states to establish goals and emission reduction strategies for
improving visibility in all the Class 1 areas. The rule contains specific
provisions (section 309 of the rule) to allow the western states to implement
the Grand Canyon Visibility Transport Commission's recommendations within the
framework of the rule. The western states are not obligated to select section
309 of the rule; they may, instead, decide to use section 308 of the rule. The
Company cannot predict at this time what the impact of the implementation of the
regional haze rule (either section 308 or 309) will be on the Company's
coal-fired power plant operations. Potentially, additional SO2 emission
reductions could be required in the 2013-2018 timeframe. The nature and cost of
the impacts of these requirements cannot be determined at this time. However,
the Company does not anticipate any material adverse impact on the Company's
financial condition or results of operations.
In July 1997, the EPA issued its final rules revising the National
Ambient Air Quality Standards for ozone and particulate matter. In May 1999, the
U.S. Court of Appeals for the D.C. Circuit remanded both of the standards to the
EPA. In October 1999, the D.C. Circuit denied EPA's petition for rehearing. The
nature and cost of the impacts of these revisions to the standards, if any, to
the Company's operations cannot be determined at this time. However, the Company
does not anticipate any material adverse impact on the Company's financial
condition or results of operations.
APS, as the operating agent of Four Corners, previously filed a petition
for review alleging EPA improperly classified Four Corners Unit 4 with respect
to nitrogen oxides emission limitations. In December 1999, EPA issued a direct
final rule, which classified Four Corners Unit 4 as APS proposed. APS does not
currently expect this rule to have a material impact on the Four Corners
operations.
18
In a related matter, in September 1999, the EPA proposed a FIP to set
air quality standards at certain power plants, including Four Corners. The
comment period on this proposal ended in November 1999. The FIP is similar to
current New Mexico regulation of Four Corners with minor modifications. APS does
not currently expect the FIP to have a material impact on the Four Corners
operations.
The EPA has proposed changes to its New Source Review (NSR) rules that
could result in many actions at power plants that have always been considered
routine repair and maintenance activities (and hence not subject to the
application of NSR requirements) as now being subject to NSR. The EPA has been
holding stakeholder meetings to try to reach a resolution on this issue that is
acceptable to the utility industry, regulatory agencies, and environmental
groups. No agreement had been reached by the end of February 2000.
In November 1999, the Department of Justice at the request of the EPA
filed complaints against eight companies alleging the companies over the past 25
years had made modifications to their plants in violation of the NSR
requirements, and in some cases the New Source Performance Standards (NSPS)
regulations. The activities cited in the complaints are all routine maintenance,
repair, and replacement activities that are excluded from the permitting
requirements of NSR and NSPS. Whether or not the EPA will prevail is unclear at
this time. The Company believes that all of the routine maintenance, repair, and
replacement work undertaken at its power plants was and continues to be in
accordance with the requirements of NSR and NSPS.
The nature and cost of the impacts of EPA's changed interpretation of
the application of the NSR and NSPS, together with proposed changes to these
regulations, may be significant to the power production industry. However, the
Company cannot quantify these impacts, and does not anticipate any material
adverse impact on the Company's financial condition or results of operations at
this time.
Santa Fe Generating Station ("Santa Fe Station")
The Company and the NMED have conducted investigations of the gasoline
and chlorinated solvent groundwater contamination detected beneath the former
Santa Fe Station site to determine the source of the contamination pursuant to a
1992 Settlement Agreement ("Settlement Agreement") between the Company and the
NMED. In June 1996, the Company received a letter from the NMED, indicating that
the NMED believes the Company is the source of gasoline contamination in a City
of Santa Fe municipal supply well and of groundwater underlying the Santa Fe
Station site. Further, the NMED letter stated that the Company was required to
proceed with interim remediation of the contamination pursuant to the New Mexico
Water Quality Control Commission regulations.
In October 1996, the Company and the NMED signed an amendment to the
Settlement Agreement concerning the groundwater contamination underlying the
site. As part of the amendment, the Company agreed to spend approximately $1.2
million for certain costs related to sampling, monitoring, and the development
and implementation of a remediation plan.
The amended Settlement Agreement does not, however, provide the Company
with a full and complete release from potential further liability for
remediation of the groundwater contamination. After the Company has expended the
settlement amount, if the NMED can establish through binding arbitration that
the Santa Fe Station is the source of the contamination, the Company could be
required to perform further remediation that is determined to be necessary. The
Company continues to dispute any contention that the Santa Fe Station is the
source of the groundwater contamination and believes that insufficient data
exists to identify the sources of groundwater contamination. The Company's
aquifer characterization and groundwater quality reports compiled from 1996 to
2000 strongly suggest groundwater contamination has been drawn under the site by
the pumping of the Santa Fe supply well.
19
The Company and the NMED, with the cooperation of the City of Santa Fe,
jointly selected a remediation plan proposed by a remediation contractor. The
City of Santa Fe, the Company and the NMED entered into a memorandum of
understanding concerning the selected remediation plan and the operation of the
municipal well adjacent to the Santa Fe Station site in connection with carrying
out that plan. Construction of a new Santa Fe well and booster station has been
completed. The new system began operation on October 5, 1998, to treat
groundwater produced by the Santa Fe well to drinking water standards for
municipal distribution and the stimulation of naturally occurring bioremediation
of groundwater contamination beneath the Santa Fe Station site. Since the
reactivation of the Santa Fe well, the groundwater treatment and bioremediation
systems have resulted in a marked reduction in contaminant concentrations at the
wellhead. However, contaminant concentrations at the property boundary remain
high.
Person Station
The Company, in compliance with a Corrective Action Directive issued by
the NMED, determined that groundwater contamination exists in the deep and
shallow groundwater at the Person Station site. The Company is required to
delineate the extent of the contamination and remediate the contaminants in the
groundwater at the Person Station site. The extent of shallow and deep
groundwater contamination was assessed and the results were reported to the
NMED. The Company currently is involved with the process to renew the RCRA
post-closure care permit for the facility. Remedial actions for the shallow and
deep groundwater will be incorporated into the new permit. The Company has
installed and is operating a pump and treat system for the shallow groundwater.
The Company has proposed a monitoring program in conjunction with natural
attenuation processes as the most cost effective approach for the deep
groundwater remediation. The Company's current estimate to decommission its
retired fossil-fueled plants (discussed below) includes approximately $4.6
million in additional expenses to complete the groundwater remediation program
at Person Station. As part of the financial assurance requirement of the Person
Station Hazardous Waste Permit, the Company established a trust fund. The
current value of the trust fund at December 31, 1999, was approximately $4.5
million. The remediation program continues on schedule.
Fossil-Fueled Plant Decommissioning Costs
The Company's six owned or partially owned, in service and retired,
fossil-fueled generating stations are expected to incur dismantling and
reclamation costs as they are decommissioned. The Company's share of
decommissioning costs for all of its fossil-fueled generating stations is
projected to be approximately $153.5 million stated in 1999 dollars, including
approximately $24.0 million (of which $15.5 million has already been expended)
for Person, Prager and Santa Fe Stations which have been retired. The Company is
currently recovering estimated decommissioning costs for its in-service
fossil-fueled generating facilities through rates charged to its retail
customers.
20
ITEM 2. PROPERTIES
The Company's owned interests in PVNGS are mortgaged to secure its
remaining first mortgage bonds.
ELECTRIC
The Company's ownership and capacity in electric generating stations in
commercial service as of December 31, 1999, were as follows:
Total Net
Generation
Capacity
Type Name Location (MW)
- --------------- ----------------- ------------------------- -----------
Nuclear........ PVNGS (a) Wintersburg, Arizona 390 *
Coal........... SJGS (b) Waterflow, New Mexico 765
Coal........... Four Corners (c) Fruitland, New Mexico 192
Gas/Oil........ Reeves Albuquerque, New Mexico 154
Gas/Oil........ Las Vegas Las Vegas, New Mexico 20
-----
1,521
=====
* For load and resource purposes, the Company has notified the PRC that it
recognizes the maximum dependable capacity rating for PVNGS to be 381 MW.
-----------------
(a) The Company is entitled to 10.2% of the power and energy
generated by PVNGS. The Company has a 10.2% ownership interest in
Unit 3 and has leasehold interests in approximately 7.9% of Units
1 and 2 and an ownership interest in approximately 2.3% of Units
1 and 2.
(b) SJGS Units 1, 2 and 3 are 50% owned by the Company; SJGS Unit 4
is 38.5% owned by the Company.
(c) Four Corners Units 4 and 5 are 13% owned by the Company.
Fossil-Fueled Plants
SJGS is located in northwestern New Mexico, and consists of four units
operated by the Company. Units 1, 2, 3 and 4 at SJGS have net rated capacities
of 327 MW, 316 MW, 497 MW and 507 MW, respectively. SJGS Units 1 and 2 are owned
on a 50% shared basis with Tucson. Unit 3 is owned 50% by the Company, 41.8% by
SCPPA and 8.2% by Tri-State. Unit 4 is owned 38.457% by the Company, 28.8% by
M-S-R, 10.04% by Anaheim, 8.475% by Farmington, 7.2% by Los Alamos and 7.028% by
UAMPS.
In July 1996, the Company and other SJGS participants signed an
agreement to convert the flue gas desulfurization (SO2 removal) system at the
SJGS into a much simpler and cost effective limestone system. The conversion
project was completed in January 1999 and cost the Company approximately $40
million.
21
The Company also owns 192 MW of net rated capacity derived from its 13%
interest in Units 4 and 5 of Four Corners located in northwestern New Mexico on
land leased from the Navajo Nation and adjacent to available coal deposits.
Units 4 and 5 at Four Corners are jointly owned with SCE, APS, Salt River
Project, Tucson and El Paso and are operated by APS.
Four Corners and a portion of the facilities adjacent to SJGS are
located on land held under easements from the United States and also under
leases from the Navajo Nation. The enforcement of these leases could require
Congressional consent. The Company does not deem the risk with respect to the
enforcement of these easements and leases to be material. However, the Company
is dependent in some measure upon the willingness and ability of the Navajo
Nation to protect these properties.
The Company owns 154 MW of generation capacity at Reeves Station in
Albuquerque, New Mexico, and 20 MW of generation capacity at Las Vegas Station
in Las Vegas, New Mexico. These stations are used primarily for peaking and
transmission support.
Nuclear Plant
The Company's Interest in PVNGS
The Company is participating in the three 1,270 MW units of PVNGS, also
known as the Arizona Nuclear Power Project, with APS (the operating agent), Salt
River Project, El Paso, SCE, SCPPA and The Department of Water and Power of the
City of Los Angeles. The Company has a 10.2% undivided interest in PVNGS, with
portions of its interests in Units 1 and 2 held under leases. During 1999, PVNGS
was operated at a capacity factor of 93.0% which was the highest yearly capacity
factor attained at the plant. This capacity factor was primarily attributable to
record setting low refueling outage days.
Nuclear Safety Performance Rating on PVNGS
On April 8, 1998, APS received its latest Systematic Assessment of
Licensee Performance ("SALP") rating from the NRC on the operations of the PVNGS
units. The SALP reports rate safety performance at nuclear plants in four
functional areas: (i) plant operations; (ii) maintenance; (iii) engineering; and
(iv) plant support. Ratings of category 1, 2, or 3 are assigned, reflecting
"superior," "good" or "adequate" performance. PVNGS was rated as "superior" in
maintenance, engineering and plant support categories, and was rated as "good"
in the area of plant operations.
In 2000, the NRC will begin using a new, objective oversight process
that is more focused on safety. The new process includes objective performance
thresholds based on insights from safety studies and 30 years of plant operating
experience. It is more timely, moving from the 18 to 24 month time lag of the
old process for assessing plant performance to a quarterly review. The NRC also
hopes the process will prove to be more accessible to, and readily understood
by, the public.
22
Steam Generator Tubes
APS, as the operating agent of PVNGS, has encountered tube cracking in
the steam generators and has taken, and will continue to take, remedial actions
that it believes have slowed the rate of tube degradation. The projected service
life of steam generators is reassessed periodically and these analyses indicate
that it will be economically desirable to replace the Unit 2 steam generators in
2003. In 1997, the PVNGS participants, including the Company, entered into a
contract for the fabrication of two replacement steam generators. The cost of
the new steam generators was updated in late 1999. The Company's share of the
fabrication and installation costs will be approximately $22.5 million.
Based on later available data, APS estimates that the Unit 1 and Unit 3
steam generators should operate for the license periods (until 2025 and 2027,
respectively), although APS will continue its normal periodic assessment of
these generators. The Company expects that some tube degradation will occur
through the licensed period.
Low Level Waste
A new low-level waste facility was built in 1995 on-site which could
store an amount of waste equivalent to ten years of normal operation at PVNGS.
Although some low-level waste has been stored on-site, APS is currently shipping
low-level waste to off-site facilities. APS currently believes that interim
low-level waste storage methods are or will be available to PVNGS to allow its
continued operation and to safely store low-level waste until a permanent
disposal facility is available.
Sale and Leaseback Transactions of PVNGS Units 1 and 2
In 1985 and 1986, the Company entered into a total of eleven sale and
lease back transactions under which it sold and leased back its entire 10.2%
interest in PVNGS Units 1 and 2, together with portions of the Company's
undivided interest in certain PVNGS common facilities. The leases under each of
the sale and leaseback transactions have initial lease terms expiring January
15, 2015 (with respect to the Unit 1 leases) or January 15, 2016 (with respect
to the Unit 2 leases). Each of the leases allows the Company to extend the term
of the lease as well as containing a repurchase option. The lease expense for
the Company's PVNGS leases is approximately $66.3 million per year. Throughout
the terms of the leases, the Company continues to have full and exclusive
authority and responsibility to exercise and perform all of the rights and
duties of a participant in PVNGS under the Arizona Nuclear Power Project
Participation Agreement and retains the exclusive right to sell and dispose of
its 10.2% share of the power and energy generated by PVNGS Units 1 and 2. The
Company also retains responsibility for payment of its share of all taxes,
insurance premiums, operating and maintenance costs, costs related to capital
improvements and decommissioning and all other similar costs and expenses
associated with the leased facilities. In 1992, the Company purchased
approximately 22% of the beneficial interests in the PVNGS Units 1 and 2 leases.
The related ownership interests were subsequently reacquired by the Company. In
connection with the $30 million retail rate reduction stipulated with the NMPUC
in 1994, the Company wrote down the purchased beneficial interests in PVNGS
Units 1 and 2 leases to $46.7 million.
23
Each lease describes certain events, "Events of Loss" or "Deemed Loss
Events", the occurrence of which could require the Company to, among other
things, (i) pay the lessor and the equity investor, in return for such
investor's interest in PVNGS, cash in the amount provided in the lease and (ii)
assume debt obligations relating to the PVNGS lease. The "Events of Loss"
generally relate to casualties, accidents and other events at PVNGS, which would
severely adversely affect the ability of the operating agent, APS, to operate,
and the ability of the Company to earn a return on its interests in, PVNGS. The
"Deemed Loss Events" consist mostly of legal and regulatory changes (such as
changes in law making the sale and leaseback transactions illegal, or changes in
law making the lessors liable for nuclear decommissioning obligations). The
Company believes the probability of such "Events of Loss" or "Deemed Loss
Events" occurring is remote. Such belief is based on the following reasons: (i)
to a large extent, prevention of "Events of Loss" and some "Deemed Loss Events"
is within the control of the PVNGS participants, including the Company, and the
PVNGS operating agent, through the general PVNGS operational and safety
oversight process and (ii) with respect to other "Deemed Loss Events", which
would involve a significant change in current law and policy, the Company is
unaware of any pending proposals or proposals being considered for introduction
in Congress, except as described below under "PVNGS Liability and Insurance
Matters", or any state legislative or regulatory body that, if adopted, would
cause any such events.
PVNGS Decommissioning Funding
The Company has a program for funding its share of decommissioning costs
for PVNGS. (See ITEM 3. - "LEGAL PROCEEDINGS - Nuclear Decommissioning Trust".)
The nuclear decommissioning funding program is invested in equities and fixed
income investments in qualified and non-qualified trusts. The results of the
1998 decommissioning cost study indicated that the Company's share of the PVNGS
decommissioning costs excluding spent fuel disposal will be approximately $163.1
million (in 1999 dollars).
The Company funded an additional $3.1 million, $3.0 million and $2.1
million in 1999, 1998 and 1997, respectively, into the qualified trust funds.
The estimated market value of the trusts at the end of 1999 was approximately
$51.8 million.
The NRC amended its rules on financial assurance requirements for the
decommissioning of nuclear power plants. The amended rules became effective on
November 23, 1998. The NRC has indicated that the amendments respond to the
potential rate deregulation in the power generating industry and NRC concerns
regarding whether decommissioning funding assurance requirements will need to be
modified. The amended rules provide that a licensee may use an external sinking
fund as the exclusive financial assurance mechanism if the licensee recovers
amounts equal to estimated total decommissioning costs through cost of service
rates or through a "non-bypassable charge". Other mechanisms are prescribed,
such as prepayment, surety methods, insurance and other guarantees, if the
requirements for exclusive reliance on the external sinking fund mechanism are
not met. The Company currently relies on the external sinking fund mechanism to
meet the NRC financial assurance requirements for its interests in PVNGS Units
1, 2 and 3. The costs of PVNGS Units 1 and 2 are currently included in PRC
jurisdictional rates, but the costs of PVNGS Unit 3 are excluded from PRC
jurisdictional rates. The Company filed a report with the NRC through APS, the
operating agent of PVNGS, at the end of March 1999, concerning decommissioning
funding assurance, and continues to use the external sinking fund method as the
sole financial assurance method for Unit 3 (see ITEM 7. "MANAGEMENT'S DISCUSSION
AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - The
Restructuring Act and the Formation of a Holding Company - NRC Prefunding").
24
Nuclear Spent Fuel and Waste Disposal
Pursuant to the Waste Act, the DOE is obligated to accept and dispose of
all spent nuclear fuel and other high-level radioactive wastes generated by
domestic power reactors. The NRC, pursuant to the Waste Act, requires operators
of nuclear power reactors to enter into spent fuel disposal contracts with DOE.
Under the Waste Act, DOE was to develop the facilities necessary for the storage
and disposal of spent nuclear fuel and to have the first such facility in
operation by 1998. That facility was to be a permanent repository. The DOE has
announced that such a repository now cannot be completed before 2010. In July
1996, the United States Court of Appeals for the District of Columbia Circuit
(D. C. Circuit) ruled that the DOE has an obligation to start disposing of spent
nuclear fuel no later than January 31, 1998. By way of letter dated December 17,
1996, the DOE informed the Company and other contract holders that the DOE
anticipates that it would be unable to begin acceptance of nuclear spent fuel
for disposal in a repository or interim storage facility by January 31, 1998. In
November 1997, the D. C. Circuit issued a Writ of Mandamus precluding the DOE
from excusing its own delay on the grounds that the DOE has not yet prepared a
permanent repository or interim storage facility. On May 5, 1998, the D. C.
Circuit issued a ruling refusing to order the DOE to begin moving spent nuclear
fuel. See note 12 of Notes to the Consolidated Financial Statements in Item 8
for a discussion of interim spent fuel storage costs.
Several bills have been introduced in Congress contemplating the
construction of a central interim storage facility; however, there is resistance
to certain features of these bills, both in Congress and the Administration.
Facility funding is a further complication. While all nuclear utilities
pay into a so-called nuclear waste fund, an amount calculated on the basis of
the output of their respective plants, the annual Congressional appropriations
for the permanent repository have been for amounts less than the amounts paid
into the waste fund (the balance of which is being used for other purposes). The
DOE has stated the fund may now be at a level less than needed to achieve a 2010
operational date for a permanent repository. No funding will be available for a
central interim facility until one is authorized by Congress.
APS has storage capacity in existing fuel storage pools at PVNGS which,
with certain modifications, could accommodate all fuel expected to be discharged
from normal operation of PVNGS through about 2002. Construction of a new
facility for on-site dry storage of spent fuel is underway. Once this facility
is completed and approvals are granted, APS believes that spent fuel storage or
disposal methods will be available for use by PVNGS to allow its continued
operation beyond 2002.
A new low-level waste facility was built in 1995 on site, which could
store an amount of waste equivalent to ten years of normal operation at PVNGS.
Although some low-level waste has been stored on site, APS is currently shipping
low-level waste to off-site facilities. APS currently believes that interim
low-level waste storage methods are or will be available for use by PVNGS to
allow its continued operation and to safely store low-level waste until a
permanent disposal facility is available.
25
The Company believes that scientific and financial aspects of the issues
of spent fuel and low-level waste storage and disposal can be resolved
satisfactorily. However, the Company also acknowledges that their ultimate
resolution in a timely fashion will require political resolve and action on
national and regional scales which the Company is unable to predict at this
time.
PVNGS Liability and Insurance Matters
The PVNGS participants have insurance for public liability resulting
from nuclear energy hazards to the full limit of liability under Federal law.
This potential liability is covered by primary liability insurance provided by
commercial insurance carriers in the amount of $200 million and the balance by
an industry-wide retrospective assessment program. If losses at any nuclear
power plant covered by the program exceed the primary liability insurance limit,
the Company could be assessed retrospective premium adjustments. The maximum
assessment per reactor under the program for each nuclear incident is
approximately $88 million, subject to an annual limit of $10 million per reactor
per incident. Based upon the Company's 10.2% interest in the three PVNGS units,
the Company's maximum potential assessment per incident for all three units is
approximately $26.9 million, with an annual payment limitation of $3 million per
incident. The insureds under this liability insurance include the PVNGS
participants and "any other person or organization with respect to his legal
responsibility for damage caused by the nuclear energy hazard". If the funds
provided by this retrospective assessment program prove to be insufficient,
Congress could impose revenue raising measures on the nuclear industry to pay
claims.
The NRC announced that it had provided a report to Congress, making
certain recommendations, with respect to the Federal law referred to above,
which provides for payment of public liability claims in case of a catastrophic
accident involving a nuclear power plant. One of the recommendations by the NRC
would be that Congress consider amending the law to provide that the maximum a
nuclear utility can be assessed per reactor per incident per year be doubled to
$20 million. The $88 million maximum retrospective assessment per reactor per
incident would be unchanged under the NRC proposal. The NRC also recommended
that Congress investigate whether the $200 million now available from the
private insurance market for liability claims per reactor can be increased to
keep pace with inflation. The Company cannot predict whether or not Congress
will act on the NRC's recommendations. However, if adopted, certain of the
recommendations could possibly trigger "Deemed Loss Events" under the Company's
PVNGS leases, absent waiver by the lessors.
The PVNGS participants maintain "all-risk" (including nuclear hazards)
insurance for nuclear property damage to, and decontamination of, property at
PVNGS in the aggregate amount of $2.75 billion as of January 1, 2000, a
substantial portion of which must be applied to stabilization and
decontamination. The Company has also secured insurance against portions of the
increased cost of generation or purchased power and business interruption
resulting from certain accidental outages of any of the three units if the
outages exceed 12 weeks. The insurance coverage discussed in this section is
subject to certain policy conditions and exclusions. The Company is a member of
an industry mutual insurer. This mutual insurer provides both the "all-risk" and
increased cost of generation insurance to the Company. In the event of adverse
losses experienced by this insurer, the Company is subject to an assessment. The
Company's maximum share of any assessment is approximately $2.6 million per
year.
26
Other Electric Properties
As of December 31, 1999, the Company owned, jointly owned or leased
2,803 circuit miles of electric transmission lines, 4,399 miles of distribution
overhead lines, 3,590 cable miles of underground distribution lines (excluding
street lighting) and 214 substations.
Acquisition of Certain Assets of Plains Electric Generation and Transmission
Cooperative, Inc. ("Plains")
In July 1998, the Company and Tri-State Generation and Transmission Association,
Inc. ("Tri-State") made a non-binding joint proposal in response to a request
for proposals issued by Plains. The Company and Tri-State submitted a binding
proposal in September 1998, and Plains announced that it would enter into
exclusive negotiations with the Company and Tri-State regarding this joint
proposal. In September 1999, Plains and Tri-State agreed to merge, with
Tri-State being the surviving entity. Following the merger, Tri-State will sell
certain assets to the Company consisting primarily of transmission assets, a
fifty percent interest in an inactive power plant located near Albuquerque and
the Plains headquarters building in Albuquerque. In addition, the Company
entered into an agreement to become the power supplier of 50 MW to Navopache
Electric Cooperative, Inc.
In early 1999, the Company, Tri-State and Plains filed applications with
the PRC seeking approval of the various transactions. The parties to that
proceeding entered into a stipulation that would have approved the transactions.
On January 19, 2000, the hearing examiner issued a recommended decision
disapproving the stipulation because, among other things, provisions of the
stipulation, relating to the PRC's jurisdiction over Tri-State after the merger,
were not in the public interest. On February 8, 2000, Plains and Tri-State filed
exceptions to the recommended decision. In addition, on January 20, 2000, a bill
was introduced in the New Mexico Legislature that would restrict the
jurisdiction of the PRC over generation and transmission cooperatives like
Tri-State. The bill passed both the House and the Senate and it has now been
signed by the governor. On February 22, 2000, the PRC, noting that the
Legislature had passed legislation containing jurisdictional restrictions
similar to the stipulation, declined to adopt the recommended decision and
instead adopted the stipulation with jurisdiction over Tri-State being in
conformance with the laws of the State of New Mexico.
The Company and Tri-State entered into an asset sale agreement dated
September 9, 1999, pursuant to which Tri-State has agreed to sell the
above-referenced assets to the Company. The purchase price is $13.2 million,
subject to adjustment at the time of closing. The asset sale agreement contains
standard covenants and conditions for this type of agreement. Currently, the
parties anticipate that the merger will occur in the summer of 2000 and with all
asset transfers to the Company to be completed by approximately the fall of
2000.
NATURAL GAS
The natural gas properties as of December 31, 1999, consisted primarily
of natural gas storage, transmission and distribution systems. Provisions for
storage made by the Company include ownership and operation of an underground
storage facility located near Albuquerque, New Mexico. The transmission systems
consisted of approximately 1,334 miles of pipe with appurtenant compression
facilities. The distribution systems consisted of approximately 10,693 miles of
pipe.
27
On June 21, 1996, the Company entered into a purchase agreement with the
DOE for the purchase of approximately 130 miles of transmission pipe for $3.1
million for the transmission of natural gas to Los Alamos and to certain other
communities in northern New Mexico. The acquisition by the Company was approved
by the NMPUC in December 1996. Final right-of-way clearances were obtained in
July 1999. Effective August 1, 1999, the DOE delivered to the Company a Quit
Claim Deed conveying the pipeline and all land interests associated with the
pipeline. The transfer effectively terminated the Company's existing lease
agreement with the DOE. The Company will pay the $3.1 million by providing
transportation services to Los Alamos National Laboratory for a period not to
exceed three years. Any part of the remaining purchase price still due after
three years may either be remitted to the government in a final lump sum cash
payment or used for additional transportation services.
OTHER INFORMATION
The electric and gas transmission and distribution lines are generally
located within easements and rights-of-way on public, private and Indian lands.
The Company leases interests in PVNGS Units 1 and 2 and related property, EIP
and associated equipment, data processing, communication, office and other
equipment, office space, utility poles (joint use), vehicles and real estate.
The Company also owns and leases service and office facilities in Albuquerque
and in other operating divisions throughout its service territory.
ITEM 3. LEGAL PROCEEDINGS
PVNGS WATER SUPPLY LITIGATION
The Company understands that a summons served on APS in 1986 required
all water claimants in the Lower Gila River Watershed of Arizona to assert any
claims to water on or before January 20, 1987, in an action pending in the
Maricopa County Superior Court. PVNGS is located within the geographic area
subject to the summons and the rights of the PVNGS participants, including the
Company, to the use of groundwater and effluent at PVNGS are potentially at
issue in this action. APS, as the PVNGS project manager, filed claims that
dispute the court's jurisdiction over the PVNGS participants' groundwater rights
and their contractual rights to effluent relating to PVNGS and, alternatively,
seek confirmation of such rights. Issues important to the claims are pending in
an interlocutory appeal to the Arizona Supreme Court. No trial date concerning
the water rights claims has been set in this matter. Although the foregoing
remains subject to further evaluation, APS expects that the described litigation
will not have a material adverse impact on the operation of PVNGS.
SAN JUAN RIVER ADJUDICATION
In 1975, the State of New Mexico filed an action entitled State of New
Mexico v. United States, et al., in the District Court of San Juan County, New
Mexico, to adjudicate all water rights in the "San Juan River Stream System".
The Company was made a defendant in the litigation in 1976. The action is
expected to adjudicate water rights used at Four Corners and at SJGS. (See ITEM
1. "BUSINESS - ELECTRIC OPERATIONS - Fuel and Water Supply - Water Supply".) The
Company cannot at this time anticipate the effect, if any, of any water rights
adjudication on the present arrangements for water at SJGS and Four Corners. It
is the Company's understanding that final resolution of the case cannot be
expected for several years and is unable to predict the ultimate outcome.
28
OTHER PROCEEDINGS
Republic Savings Bank Litigation
In 1992, Meadows and RHC filed suit against the Federal government in
the United States Court of Claims, alleging breach of contract arising from the
seizure of RSB, a wholly-owned subsidiary of RHC. RSB was seized and liquidated
after the Financial Institutions Reform, Recovery and Enforcement Act prohibited
certain accounting practices authorized by contracts with the Federal
government. The Federal government filed a counterclaim alleging breach by RHC
of its obligation to maintain RSB's net worth and moved to dismiss Meadows'
claims for lack of standing.
RSB filed a motion for partial summary judgment on the issue of
liability based on the United States Supreme Court's decision in United States
v. Winstar Corporation, decided in 1996. The Federal government filed a cross
motion for summary judgment and opposed RSB's motion. Decision on those motions
is still pending. The parties completed fact based discovery in 1999 and are in
the process of discovery of experts. No trial date has been established. RSB
amended its summary judgment motion in December 1999, to seek summary judgment
on the issue of damages. The Federal government will oppose RSB's amended
motion. It is premature to estimate the amount of recovery, if any, by Meadows
and RHC.
Purported Navajo Environmental Regulation
Four Corners is located on the Navajo Reservation and is held under
easement granted by the Federal government as well as leases from the Navajo
Nation. APS is the operating agent and the Company owns a 13% ownership interest
in Units 4 and 5 of Four Corners. In July 1995, the Navajo Nation enacted the
Navajo Nation Air Pollution Prevention and Control Act, the Navajo Nation Safe
Drinking Water Act and the Navajo Nation Pesticide Act (collectively, the
"Acts"). Pursuant to the Acts, the Navajo Nation Environmental Protection Agency
is authorized to promulgate regulations covering air quality, drinking water and
pesticide activities, including those that occur at Four Corners. By letter
dated October 12, 1995, the Four Corners participants requested the United
States Secretary of the Interior (the "Secretary") to resolve their dispute with
the Navajo Nation regarding whether or not the Acts apply to operation of Four
Corners. The Four Corners participants subsequently filed a lawsuit in the
District Court of the Navajo Nation (the "Court"), Window Rock District, seeking
a declaratory judgment that: (i) the Four Corners leases and Federal easements
preclude the application of the Acts to the operation of Four Corners and (ii)
the Navajo Nation and its agencies and courts lack adjudicatory jurisdiction to
determine the enforceability of the Acts as applied to Four Corners. In October
1995, the Navajo Nation and the Four Corners participants agreed to indefinitely
stay the proceedings so that the parties may attempt to resolve the dispute
without litigation, and the Secretary and the Court stayed these proceedings
pursuant to a request by the parties. The Company is unable to predict the
outcome of this matter.
In February 1998, the EPA issued regulations specifying provisions of
the Clean Air Act for which it is appropriate to treat Indian tribes in the same
manner as states. The EPA indicated that it believes that the Clean Air Act
generally would supersede pre-existing binding agreements that may limit the
scope of tribal authority over reservations. APS and the Company have filed
appeals, which have been consolidated, in the United States Circuit Court of
Appeals for the District of Columbia ("D. C. Circuit") to contest EPA's
authority under the regulations. The Navajo Nation has intervened in the
consolidated appeal. The Navajo Nation is a tribe which could potentially assert
its status as a state under the Act pursuant to the EPA rule in question. In the
consolidated appeal, the Company's interests as operator and joint owner of the
SJGS, owner of other facilities located on reservations located in New Mexico,
and joint owner of Four Corners are involved.
29
In February 1999, the EPA issued regulations under which Federal
operating permits for stationary sources in Indian country can be issued
pursuant to Title V of the Clean Air Act. The regulations rely on authority
contained in an earlier rule in which the EPA outlined treatment of tribes as
states under the Clean Air Act. That rule is the subject of an appeal as
described above. APS and the Company have filed appeals, which have also been
consolidated in the D. C. Circuit to contest the EPA's authority under the
regulations. In the consolidated appeal, the Company's interests as operator and
joint owner of the SJGS, owner of other facilities located on reservations
located in New Mexico, and joint owner of Four Corners are involved. This appeal
has been stayed pending the outcome of the other appeal described above. The
Company cannot predict the outcome of the consolidated appeal.
Nuclear Decommissioning Trust
In 1998, the Company and the trustee of the Company's master
decommissioning trust filed a civil complaint and an amended complaint,
respectively, against several companies and individuals for the
under-performance of a corporate owned life insurance program. The program,
which was approved by the NMPUC and set up in a trust in 1987, was used to fund
a portion of the Company's nuclear decommissioning obligations for its 10.2%
interest in PVNGS. In January 1999, the life insurance program was terminated,
and the life insurance policies were surrendered by the trust in exchange for
the cash surrender value of the policies. In the lawsuit, the Company asserted
various tort, contract and equity theories against the defendants, seeking,
among other things, an amount sufficient to compensate for the harm to the
Company caused by the defendants' conduct. A defendant counterclaimed for
indemnity based on its engagement contract with the Company, claiming that if it
had injured the trustee, then the Company must pay the damages. The Company
denied liability under the counterclaim and set forth numerous defenses. The
case is proceeding in State District Court in Santa Fe County. The defendants'
motions to dismiss were denied and the Company's motions to further amend the
complaint to assert claims against two additional defendants, a law firm and an
accounting firm, were granted.
On August 13, 1999, the Company appealed one of the trial court's
decisions regarding pretrial discovery to the New Mexico Court of Appeals. While
this decision is on appeal, all pretrial discovery is being stayed. The Company
is currently unable to predict the ultimate outcome or amount of recovery, if
any.
30
Royalty Claims
Natural Gas Royalties Qui Tam Litigation
On June 28, 1999, a complaint was served on the Company alleging
violations of the False Claims Act by the Company and its subsidiaries,
Gathering Company and Processing Company (collectively called Company, for
purposes of this discussion), by purportedly failing to properly measure natural
gas from Federal and tribal properties in New Mexico, and consequently,
underpaid royalties owed to the Federal government. A private relator is
pursuing the lawsuit. The complaint was served after the United States
Department of Justice declined to intervene to pursue the lawsuit. The complaint
seeks actual damages, treble damages, costs and attorneys fees, among other
relief.
This case was consolidated with approximately 70 others, asserting
similar claims against other defendants in other jurisdictions, and transferred
to Federal District Court for the District of Wyoming by the Federal
Multi-District Litigation panel (MDL Panel), recaptioned as In re: Natural Gas
Royalties Qui Tam Litigation, MDL Docket No. 1293. The Company joined 250 other
defendants in a motion to dismiss the complaint for failure to plead properly in
November 1999. The motion is set for oral argument on March 17, 2000.
The Company is vigorously defending this lawsuit and is unable to
estimate the potential liability, if any, or to predict the ultimate outcome of
this lawsuit.
Quinque Operating Co. et al. v. Gas Pipelines, et al
A class action lawsuit against 233 defendants, including the Company,
captioned Quinque Operating Co. et al. v. Gas Pipelines, et al., C.A. No.
99-CV-30, was filed in the state district court for Stevens County, Kansas by
representatives of classes of gas producers, royalty owners, overriding royalty
owners and working interest owners, alleging that the defendants, all engaged in
various aspects of the natural gas industry, mismeasured natural gas and
underpaid royalties for gas produced on non-federal and non-tribal lands. The
claims for relief are based on Kansas state law, including a breach of contract
claim. They are factually similar, however, to the allegations of In re: Natural
Gas Royalties Qui Tam Litigation, described above. The Quinque complaint seeks
actual damages, treble damages, costs and attorneys fees among other relief.
The Quinque case was removed to the United States District Court for the
District of Kansas. Thereafter, several defendants moved the MDL Panel to
transfer the case to the United States District Court for Wyoming and to
consolidate it with the In re: Natural Gas Royalties Qui Tam Litigation.
Plaintiffs have filed objections to the motions to consolidate and transfer and
have filed with the U. S District Court in Kansas a motion to remand the case to
state court. Both matters are awaiting decision.
The Company is vigorously defending this lawsuit and is unable to
estimate the potential liability, if any, or to predict the ultimate outcome of
this lawsuit.
31
KAFB Contract
The Company was informed that the DOE had entered into an agency
agreement with Western on behalf of KAFB, one of the Company's largest retail
electric customers, by which Western will competitively procure power for KAFB.
The proposed wholesale power procurement would begin at the expiration of KAFB's
power service contract with the Company in December 1999. On May 4, 1999, the
Company received a request for network transmission service from Western
pursuant to Section 211 of the Federal Power Act to facilitate the delivery of
wholesale power to KAFB over the Company's transmission system. The Company
denied Western's request, by letter dated June 30, 1999, citing the fact that
KAFB is and will continue to be a retail customer until the effective date KAFB
can elect customer choice service under the provisions of the Restructuring Act
of 1999 (the effective date for customer choice for KAFB is January 1, 2002,
unless extended by the PRC). The Company also cited several provisions of
Federal law that prohibit the provision of such service to Western. On September
30, 1999, DOE/Western filed a petition at the FERC requesting the FERC to
consider, on an expedited basis, ordering the Company to provide network
transmission service to Western under the Company's Open Access Transmission
Tariff on behalf of DOE and several other entities located on KAFB. The petition
claims KAFB is a wholesale customer of the Company, not a retail customer. On
October 8, 1999, Western filed a request at FERC for expedited consideration of
its petition for an order to assure continued service by the Company to KAFB
once the contract between the Company and KAFB expired on December 13, 1999. The
Company filed a separate motion to intervene, protest, and motion to dismiss
each of the petitions on October 25, 1999 and November 11, 1999, respectively.
In a separate but related proceeding, the Company and the United States
Executive Agencies on behalf of KAFB are involved in a PRC case regarding a
dispute over the specific Company tariff language under which the Company
provides retail service to KAFB. The Company agreed to continue to provide
service to KAFB after expiration of the contract, pending resolution of all
relevant issues. The Company has attempted to pursue a negotiated resolution of
the issues regarding the provision of electric service to KAFB, but has been
unsuccessful. On February 3, 2000, Western withdrew its petition for an Order to
secure continuation of service.
The net revenue loss to the Company if the Company is replaced as the
power supplier to KAFB is estimated to be approximately $7.0 million annually.
The Company is currently unable to predict the ultimate outcome of these
matters, and intends to continue to vigorously defend its position.
City of Gallup Complaint
In 1998, Gallup, Gallup Joint Utilities and the Pittsburg & Midway Coal
Mining Co. ("Pitt-Midway") filed a joint complaint and petition ("Complaint")
with the NMPUC (predecessor of the PRC). The Complaint sought an interim
declaratory order stating, among other things, that Pitt-Midway is no longer an
obligated customer of the Company, Gallup is entitled to serve Pitt-Midway and
the Company must wheel power purchased by Gallup from other suppliers over the
Company's transmission system. In September 1998, the NMPUC issued an order
without conducting a hearing, granting the requests sought in the Complaint.
32
On October 13, 1999, issued an opinion and Order annulling and vacating
the NMPUC Order, stating that: (1) Gallup does not qualify as an interested
electric utility authorized to seek a wheeling order from the NMPUC; and (2) the
NMPUC did not have the statutory authority to order Wheeling under the Public
Utility Act.
On December 1, 1999, Gallup and Pitt-Midway submitted a Joint Request to
the PRC for an expedited order to comply with the mandate of the Court, stating
that the original NMPUC Order included several other findings not specifically
overturned by the Court, and the Commission should issue an order to "affirm"
the findings and issues not disposed of by the Supreme Court. On December 13,
1999, the Company filed a response stating that the Supreme Court had annulled
and vacated the PRC remand order in its entirety, and the PRC has no
jurisdiction to reconsider the issues raised. On January 28, 2000, Gallup filed
a motion for leave to respond to the Company's response, which the company has
opposed as untimely.
The PRC has taken no action on this case other than during a working
session, in which (based on Gallup and Pitt-Midway joint motion for expedited
order on remaining issues) they requested that PRC counsel write up a procedural
order allowing the parties to resubmit the issues to the PRC. The PRC counsel
charged with that task subsequently left the PRC and the procedural order was
never completed.
Hearings were held at the FERC in late February 2000, regarding the
issue of whether the Company-Gallup Agreement requires the Company to transmit
power to Gallup for delivery at the Yah-Ta-Hey Substation. A decision on this
issue is not expected until late summer.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.
33
SUPPLEMENTAL ITEM. EXECUTIVE OFFICERS OF THE COMPANY
Executive officers, their ages, offices held with the Company in the past
five years and initial effective dates thereof, were as follows on December 31,
1999, except as otherwise noted:
Name Age Office Initial Effective Date
---- --- ------ ----------------------
B. F. Montoya (1)......... 64 Chairman, President and Chief Executive
Officer June 15, 1999
President and Chief Executive Officer August 1, 1993
R. J. Flynn................ 57 Executive Vice President, Electric and Gas
Services January 18, 1999
Senior Vice President, Electric Services December 1, 1994
W. J. Real................. 51 Executive Vice President, Energy Services and
Power Production January 18, 1999
Senior Vice President, Gas Services December 6, 1994
Senior Vice President, Utility Operations December 7, 1993
Senior Vice President, Customer Service and
Operations March 2, 1993
Executive Vice President, Gas Operations June 19, 1990
B. L. Barsky............... 55 Senior Vice President, Corporate Strategy and
Investor Relations February 19, 2000
Senior Vice President and Corporate Secretary March 6, 1999
Vice President, Strategic Analysis and Investor
Relations February 14, 1996
Director, Investor Relations and Financial Analysis July 19, 1993
M. D. Christensen.......... 51 Senior Vice President, Shared Services October 1, 1999
Senior Vice President, New Mexico Retail Services November 3, 1997
Senior Vice President, Customer Service and
Public Affairs January 9, 1996
Vice President, Public Affairs December 7, 1993
Vice President, Communications July 22, 1991
M. H. Maerki............... 59 Senior Vice President and Chief Financial Officer December 7, 1993
Senior Vice President, Administration and Chief
Financial Officer March 2, 1993
Senior Vice President and Chief Financial Officer June 1, 1988
34
Name Age Office Initial Effective Date
---- --- ------ ----------------------
P. T. Ortiz................ 49 Senior Vice President, General Counsel and Secretary
Senior Vice President, Regulatory Policy, General
Counsel and Secretary December 7, 1993
Senior Vice President, Public Policy, General
Counsel and Secretary March 2, 1993
Senior Vice President, General Counsel and
Corporate Secretary February 4, 1992
E. Padilla, Jr............. 46 Senior Vice President, Bulk Power Marketing and
Development February 8, 2000
Vice President, Bulk Power Marketing and
Development December 14, 1996
Director, Marketing and Power Contracts January 14, 1991
R. B. Ridgeway............. 41 Senior Vice President, Energy Services December 14, 1996
Vice President, Corporate Planning August 10, 1996
Director, Corporate Strategy July 2, 1994
Consultant, Competitive Analysis October 5, 1992
- ---------------------
All officers are elected annually by the Board of Directors of the
Company.
(1) Benjamin F. Montoya, Chief Executive Officer and Chairman of the
Board, has announced his decision to retire sometime within the next 18 months.
In January 2000, Jeffry E. Sterba was hired to succeed Mr. Monotya. Mr. Sterba
was Executive Vice President for USEC, Inc., a provider of fuel for nuclear
power plants, from January 1999 to March 2000. From March 1997 to December 31,
1998, Mr. Sterba was Executive Vice President and Chief Operating Officer of the
Company. From December 1994 to March 1997, Mr. Sterba was Senior Vice President,
Bulk Power Services for the Company. Mr. Sterba assumed the duties of President
in March 2000. He will assume the duties of Chief Executive Officer in June 2000
and become Chairman of the Board upon Mr. Montoya's retirement.
35
PART II
ITEM 5. MARKET FOR THE COMPANY'S COMMON EQUITY AND RELATED
STOCKHOLDER MATTERS
The Company's common stock is traded on the New York Stock Exchange.
Ranges of sales prices of the Company's common stock, reported as composite
transactions (Symbol: PNM), and dividends declared on common stock for 1999 and
1998, by quarters, are as follows:
Range of
Quarter Ended Sales Prices
------------- ------------ Dividends
High Low Per Share
---- --- ---------
1999
December 31 ..................... 18 7/8 15 7/16 $0.20
September 30 .................... 21 1/2 16 3/4 0.20
June 30 ......................... 21 1/8 16 7/8 0.40
March 31 ........................ 20 5/8 14 27/32 0.20
-----
Fiscal Year .................. 21 1/2 14 27/32 $1.00
=====
1998
December 31 ..................... 23 5/16 17 3/8 $ - *
September 30 .................... 23 3/16 19 1/16 0.20
June 30 ......................... 24 3/4 20 15/16 0.20
March 31 ........................ 24 11/16 22 1/8 0.20
-----
Fiscal Year .................. 24 3/4 17 3/8 $0.60
=====
*On January 18, 1999, the Company's Board of Directors ("Board")
declared a quarterly cash dividend of 20 cents per share of common
stock payable February 19, 1999, to shareholders of record as of
February 1, 1999.
On January 31, 2000, there were 16,013 holders of record of the Company's
common stock.
The Board set the dividend payout ratio below the industry average to
allow for dividend growth in the future and to sustain financial flexibility for
the Company to respond to potential opportunities in the evolving energy
marketplace. In establishing its dividend policy, the Board weighed the
Company's current financial position and its future business plan, as well as
the regulatory and business climate in New Mexico. Future dividend declaration
will be reviewed for action by the Board. The payment of future dividends will
depend on a number of factors, including the extent to which cash flows will
support dividends, the availability of retained earnings, the financial
circumstances and performance of the Company, the PRC's decisions on the
Company's various regulatory cases currently pending, the effect of deregulating
generation markets and market and economic conditions generally. In addition,
the ability to recover stranded costs in deregulation, future growth plans and
the related capital requirements and standard business considerations will also
affect the Company's ability to pay dividends.
Cumulative Preferred Stock
While isolated sales of the Company's cumulative preferred stock have
occurred in the past, the Company is not aware of any active trading market for
its cumulative preferred stock. Quarterly cash dividends were paid on the
Company's cumulative preferred stock at the stated rates during 1999 and 1998.
36
ITEM 6. SELECTED FINANCIAL DATA
1999 1998 1997 1996 1995
---------- ----------- ---------- ---------- ----------
(In thousands except per share amounts and ratios)
Total Operating Revenues......................... $1,157,543 $ 1,092,445 $1,020,521 $ 873,778 $ 808,465
Earnings from Continuing Operations.............. $ 79,614 $ 95,119 $ 86,497 $ 72,969 $ 75,562
Net Earnings..................................... $ 83,155 $ 82,682 $ 80,995 $ 72,580 $ 75,562
Earnings per Common Share:
Continuing Operations.......................... $ 1.93 $ 2.27 $ 2.05 $ 1.73 $ 1.72
Basic.......................................... $ 2.01 $ 1.97 $ 1.92 $ 1.72 $ 1.72
Diluted........................................ $ 2.01 $ 1.95 $ 1.91 $ 1.71 $ 1.72
Total Assets..................................... $2,723,268 $ 2,668,603 $2,407,410 $2,313,334 $2,107,908
Long-Term Debt, including Current Maturities..... $ 988,489 $ 1,008,614 $ 714,345 $ 728,889 $ 728,989
Common Stock Data:
Market price per common share at year end...... $ 16.250 $ 20.438 $ 23.688 $ 19.625 $ 17.625
Book value per common share at year end........ $ 21.79 $ 20.63 $ 19.26 $ 18.06 $ 16.82
Average number of common shares outstanding.... 41,038 41,774 41,774 41,774 41,774
Cash dividend declared per common share........ $ 1.00 $ 0.60 $ 0.68 $ 0.48 $ -
Return on Average Common Equity.................. 9.5% 9.9% 10.2% 9.8% 10.7%
Capitalization:
Common stock equity............................ 46.7% 45.4% 52.6% 50.4% 48.6%
Preferred stock without mandatory redemption
Requirements................................. 0.7 0.7 0.8 0.9 0.9
Long-term debt, less current maturities........ 52.6 53.9 46.6 48.7 50.5
------------- ------------- ------------ ----------- ------------
100.0% 100.0% 100.0% 100.0% 100.0%
============= ============= ============ =========== ============
Due to the discontinuance of the natural gas trading operations of its
Energy Services Business Unit (see note 13 of the notes to consolidated
financial statements), certain prior year amounts have been reclassified as
discontinued operations.
The selected financial data should be read in conjunction with the
consolidated financial statements, the notes to consolidated financial
statements and Management's Discussion and Analysis of Financial Condition and
Results of Operations.
37
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
The following is management's assessment of the Company's financial
condition and the significant factors affecting the results of operations. This
discussion should be read in conjunction with the Company's consolidated
financial statements and PART I, ITEM 3. - Legal Proceedings. Trends and
contingencies of a material nature are discussed to the extent known and
considered relevant.
OVERVIEW
The Company is a public utility primarily engaged in the generation,
transmission, distribution and sale of electricity and in the transmission,
distribution and sale of natural gas within the State of New Mexico. In
addition, in pursuing new business opportunities, the Company provides energy
and utility related activities through its wholly owned subsidiary, Avistar.
ELECTRIC OPERATIONS
The Company's electric operations serve four principal markets. Sales to
retail customers and sales to firm-requirements wholesale customers, sometimes
referred to collectively as "system" sales, comprise two of these markets. The
third market consists of other contracted sales to utilities for which the
Company commits to deliver a specified amount of capacity (measured in
megawatts-MW) or energy (measured in megawatt hours-MWh) over a given period of
time. The fourth market consists of economy energy sales made on an hourly basis
at fluctuating, spot-market rates. Sales to the third and fourth markets are
sometimes referred to collectively as "off-system" sales.
The Company provides retail electric service to a large area of north
central New Mexico, including the cities of Albuquerque and Santa Fe, and
certain other areas of New Mexico.As of December 31, 1999, 1998 and 1997,
approximately 361,000, 358,000 and 349,000, respectively, retail electric
customers were served by the Company.
ELECTRIC SALES BY MARKET
(Thousands of dollars)
1999 1998 1997
--------- --------- ---------
Retail .................................... $522,523 $536,417 $519,504
Firm-requirements wholesale................. 7,046 10,708 10,690
Other contracted off-system sales........... 226,773 142,115 118,876
Economy energy sales........................ 131,549 122,156 55,768
Other .................................... 24,086 23,808 17,600
--------- --------- ---------
$911,977 $835,204 $722,438
========= ========= =========
38
ELECTRIC SALES BY MARKET
(Megawatt hours)
1999 1998 1997
---------- ---------- ----------
Retail ................................. 6,803,853 6,739,874 6,534,899
Firm-requirements wholesale.............. 179,249 278,615 278,727
Other contracted off-system sales........ 6,196,499 4,033,931 3,790,081
Economy energy sales..................... 4,795,873 4,469,769 2,716,835
---------- ---------- ----------
17,975,474 15,522,189 13,320,542
========== ========== ==========
The Company has ownership interests in certain generating facilities
located in New Mexico, including Four Corners, a coal fired unit, and SJGS, a
coal fired unit. In addition, the Company has ownership and leasehold interests
in PVNGS located in Arizona. These generation assets are used to supply retail
and wholesale customers. The Company also owns Reeves, a gas and oil fired unit
and Las Vegas, a gas and oil fired unit that are used solely for reliability
purposes or to generate electricity for the wholesale market during peak demand
periods in the Company's wholesale power markets. As of December 31, 1999, the
total net generation capacity of facilities owned or leased by the Company was
1,521 MW. In addition to generation capacity, the Company purchases power in the
open market. The Company is also interconnected with various utilities for
economy interchanges and the mutual assistance in emergencies. The Company has
been actively trading in the wholesale power market and has entered into and
anticipates that it will continue to enter into power purchase agreements to
accommodate its trading activity.
NATURAL GAS OPERATIONS
The Company's gas operating division, PNMGS, distributes natural gas to
most of the major communities in New Mexico, including Albuquerque and Santa Fe,
serving approximately 426,000, 419,000 and 410,438 customers as of December 31,
1999, 1998 and 1997, respectively. PNMGS' customer base includes both
sales-service customers and transportation-service customers. Sales-service
customers purchase natural gas and receive transportation and delivery services
from PNMGS for which PNMGS receives both cost-of-gas and cost-of-service
revenues. Additionally, PNMGS makes occasional gas sales to off-system
customers. Off-system sales deliveries generally occur at interstate pipeline
interconnects with PNMGS' system. Transportation-service customers, who procure
gas independently of PNMGS and contract with PNMGS for transportation and
related services, provide PNMGS with cost-of-service revenues only.
39
PNMGS obtains its supply of natural gas primarily from sources within
New Mexico pursuant to contracts with producers and marketers. These contracts
are generally sufficient to meet PNMGS peak-day demand. PNMGS serves certain
cities which depend on EPNG or Transwestern Pipeline Company for transportation
of gas supplies. Because these cities are not directly connected to PNMGS
transmission facilities, gas transported by these companies is the sole supply
source for those cities. Such transportation is regulated by FERC.
The following table shows gas throughput by customer class:
GAS THROUGHPUT
(Millions of decatherms)
1999 1998 1997
------ ------ -------
Residential.................................... 29.3 30.3 30.7
Commercial..................................... 10.1 10.4 10.6
Industrial..................................... 2.3 1.5 1.3
Public authorities............................. 2.9 3.4 4.2
Irrigation..................................... 1.4 1.9 1.6
Sales for resale............................... 1.2 1.2 1.2
Unbilled....................................... 3.8 (1.3) (0.2)
Transportation*................................ 40.2 36.4 34.0
Off-system sales............................... 1.1 1.9 1.2
------ ------ -------
92.3 85.7 84.6
====== ====== =======
The following table shows gas revenues by customer:
GAS REVENUES
(Thousands of dollars)
1999 1998 1997
-------- --------- ----------
Residential.............................. $148,968 $161,153 $ 187,563
Commercial............................... 36,528 42,680 50,502
Industrial............................... 8,550 4,887 4,536
Public authorities....................... 9,782 12,610 17,577
Irrigation............................... 4,229 5,780 5,041
Sales for resale......................... 2,530 3,596 4,465
Unbilled................................. 4,107 (955) (2,172)
Transportation*.......................... 12,390 13,464 14,172
Liquids.................................. 1,867 1,463 4,451
Off-system sales......................... 2,357 3,816 1,926
Other.................................... 5,403 7,481 6,708
-------- --------- ----------
$236,711 $255,975 $294,769
======== ========= ==========
*Customer-owned gas.
40
AVISTAR
The Company's wholly-owned subsidiary, Avistar, was formed in August
1999 as a New Mexico corporation and is currently engaged in certain
unregulated, non-utility businesses, including energy and utility-related
services previously operated by the Company. The PRC authorized the Company to
invest $50 million in equity in Avistar and to enter into a reciprocal loan
agreement for up to $30 million. The Company has currently invested $25 million
in Avistar. In February 2000, Avistar invested $3 million in AMDAX.com, a
start-up company which will provide an on line auction service to bring together
electricity buyers and sellers in the deregulated electric power market. In
addition, Avistar entered into an agreement with Sandia Corporation to jointly
develop and market new risk and reliability software for private industry.
Avistar, also, operates and manages the City of Santa Fe's water system.
RESTRUCTURING THE ELECTRIC UTILITY INDUSTRY
Introduction of competitive market forces and restructuring of the
electric utility industry in New Mexico continue to be key issues facing the
Company. The Restructuring Act was enacted into law on April 8, 1999, opening
the state's electric power market to customer choice beginning in 2001. The law
gives schools, residential and small business customers the opportunity to
choose among competing power suppliers beginning in January 2001. Competition
will be expanded to include all customers starting in January 2002. The PRC,
however, can extend these dates by up to one year if necessary. Rural electric
cooperatives and municipal electric systems have the option not to participate
in the competitive market.
Residential and small business customers who do not select a power
supplier in the open market can buy their electricity through their local
utility through a "standard offer" whereby the local distribution utility will
purchase power supplies through a competitive process approved by the PRC. The
local distribution utility system and related services such as billing and
metering will continue to be regulated by the PRC, while the interstate
transmission system will remain subject to Federal regulation.
The law does not require utilities to divest their generating plants,
but requires unregulated activities to be separated from the regulated
activities through creation of at least two separate corporations.
The law also provides for sharing of stranded costs between utility
shareholders and customers, allowing utilities to recover at least half of such
stranded costs. Stranded costs are defined in the law to include nuclear
decommissioning costs, regulatory assets, leases and other costs recognized
under existing regulation. Utilities could be allowed to recover more than half
of their stranded costs if they meet the criteria specified in the law. Stranded
costs will be recovered from customers over a five-year period. Utilities will
also be allowed to recover through 2007 all transition costs reasonably incurred
to comply with the new law.
The law, however, does not provide a guaranteed rate cut for residential
customers. Electric rates during the transition to competition will be set by
the PRC. The Company received a recent rate case order, which did result in a
rate reduction. (See "Electric Rate Case" below.)
41
The Company is required to file a transition plan with the PRC by June
1, 2000. The transition plan must include proposals for: (i) implementing
customer choice and open access to the Company's transmission and distribution
system; (ii) separating regulated and non-regulated business activities; (iii)
recommended rates for distribution, transmission and related services; (iv)
competitive procurement process for standard offer; and (v) recovery of stranded
costs and transition costs. The Company plans to reorganize its operations by
forming a holding company structure as a means of achieving the corporate and
asset separation required by the Restructuring Act. The proposed holding company
will be called Manzano Corporation. On February 15, 2000, the PRC approved the
Company's request to form a wholly-owned shell subsidiary which will become the
holding company. The Company's plan for a holding company structure will
separate the Company into two subsidiaries. Shareholders will be asked to
approve the holding company structure. If the Company receives all necessary
regulatory and other approvals, pursuant to the Restructuring Act, all of the
Company's electric and gas distribution and transmission assets and related
liabilities will be transferred to a newly created subsidiary. After this asset
transfer, this subsidiary will acquire the name "Public Service Company of New
Mexico" (for purposes of this discussion, the subsidiary will be referred to as
"UtilityCo") and the corporation formerly named Public Service Company of New
Mexico will be renamed Manzano Energy Corporation (for purposes of this
discussion, the subsidiary will be referred to as "Energy"). Energy will
continue to own the Company's existing electric generation and unregulated,
competitive assets after completion of the transfer of the regulated business to
the newly created utility subsidiary. UtilityCo and Energy will be wholly-owned
subsidiaries of Manzano. (See "FORMATION OF HOLDING COMPANY" below.)
COMPETITIVE STRATEGY
The restructuring of the electric utility industry will provide new
opportunities; however, the Company anticipates that it will experience downward
pressure on the Company's utility earnings from their current levels. The
reasons for the downward pressure include possible limits on return on equity,
disallowance of some stranded costs and the potential loss of certain customers
in a competitive environment.
Under a holding company structure, the regulated businesses (natural gas
and electric transmission and distribution) will be grouped under a separate
company and would focus on the core utility business in New Mexico. The
unregulated businesses under the Restructuring Act (power production, bulk power
marketing and energy services) would aggressively pursue efforts to expand
energy marketing and utility related businesses into carefully targeted markets
in an effort to increase shareholders' value. The Company believes that
successful operations of its proposed unregulated business activities under a
holding company structure will better position the Company in an increasingly
competitive utility environment.
The Company's bulk power operations have contributed significant
earnings to the Company in recent years as a result of increased off-system
sales. The Company plans to expand its wholesale power trading functions which
could include an expansion of its generation portfolio. The Company continuously
evaluates its physical asset acquisition strategies to ensure an optimal mix of
base-load generation, peaking generation and purchased power in its power
portfolio.
42
In addition to the continued power trading operations, the Company will
further focus on opportunities in the market place where excess capacity is
disappearing and mid- to long-term market demands are growing.
The Company's current business plan includes a 300% increase in sales
and a doubling of its generating capacity through the construction or
acquisition of additional power generation assets in its surrounding region of
operations. Such growth will be dependent upon the Company's ability to generate
$400 to $600 million to fund the Company's expansion. There can be no assurance
that these competitive businesses, particularly the generation business, will be
successful or, if unsuccessful, that they will not have a direct or indirect
adverse effect on the Company.
At the Federal level, there are a number of proposals on electric
restructuring being considered with no concrete timing for definitive actions.
It is expected that previously introduced restructuring bills will be
re-introduced this year. Issues such as stranded cost recovery, market power,
utility regulations reform, the role of states, subsidies, consumer protections
and environmental concerns are expected to be at the forefront of the
Congressional debate. In addition, the FERC has stated that if Congress mandates
electric retail access, it should leave the details of the program to the states
and the FERC has the authority to order the necessary transmission access for
the delivery of power for the states' retail access programs.
Although it is unable to predict the ultimate outcome of retail
competition in New Mexico, the Company has been and will continue to be active
at both the state and Federal levels in the public policy debates on the
restructuring of the electric utility industry. The Company will continue to
work with customers, regulators, legislators and other interested parties to
find solutions that bring benefits from competition while recognizing the
importance of reimbursing utilities for past commitments.
43
RESULTS OF OPERATIONS
The following discussion is based on the financial information presented
in Footnote 1 of the Consolidated Financial Statements - Nature of Business and
Segment Information. The table below sets forth the operating results as
percentages of total operating revenues for each business segment.
Year Ended December 31, 1999
Electric Gas Other Consolidated
--------- --------- -------- ------------
Operating revenues................... 100.00% 100.00% 100.00% 100.00%
Cost of energy sold.................. 45.95% 47.71% 0.00% 45.96%
Cost of sales and projects........... 0.00% 0.00% 91.35% 0.70%
--------- --------- --------- --------
Gross Margin......................... 54.05% 52.29% 8.65% 53.35%
--------- --------- --------- --------
Administrative and other costs....... 9.23% 22.15% 101.82% 12.58%
Energy production costs.............. 15.27% 0.63% 0.00% 12.16%
Depreciation and amortization........ 7.99% 8.35% 0.00% 8.00%
Transmission and distribution costs.. 3.40% 11.92% 0.00% 5.12%
Taxes other than income taxes........ 3.12% 2.98% (15.90)% 2.94%
Income taxes......................... 3.03% (0.14)% (25.53)% 2.16%
--------- --------- --------- --------
Total non-fuel operating expenses.... 42.04% 45.90% 60.38% 42.97%
--------- --------- --------- --------
Operating income..................... 12.01% 6.39% (51.73)% 10.37%
--------- --------- --------- --------
Year Ended December 31, 1998
Operating revenues.................. 100.00% 100.00% 100.00% 100.00%
Cost of energy sold................. 37.68% 52.64% 0.00% 41.14%
Cost of sales and projects.......... 0.00% 0.00% 73.93% 0.09%
--------- --------- --------- --------
Gross Margin........................ 62.32% 47.36% 26.07% 58.77%
--------- --------- --------- --------
Administrative and other costs...... 9.12% 19.13% 760.66% 12.34%
Energy production costs............. 17.90% 0.09% 0.00% 13.71%
Depreciation and amortization....... 8.41% 6.20% 4.98% 7.89%
Transmission and distribution costs. 3.85% 9.51% 0.00% 5.17%
Taxes other than income taxes....... 3.67% 2.78% 20.22% 3.48%
Income taxes........................ 4.83% 1.80% (288.94%) 3.78%
--------- --------- --------- --------
Total non-fuel operating expenses... 47.78% 39.50% 496.92% 46.36%
--------- --------- --------- --------
Operating income.................... 14.55% 7.85% (470.85%) 12.42%
--------- --------- --------- --------
Year Ended December 31, 1997
Operating revenues.................. 100.00% 100.00% 100.00% 100.00%
Cost of energy sold................. 33.22% 57.59% 0.00% 40.15%
Cost of sales and projects.......... 0.00% 0.00% 79.39% 0.26%
--------- --------- --------- --------
Gross Margin........................ 66.78% 42.41% 20.61% 59.59%
--------- --------- --------- --------
Administrative and other costs...... 9.48% 16.10% 180.21% 11.95%
Energy production costs............. 19.10% 0.10% 0.00% 13.55%
Depreciation and amortization....... 9.42% 4.95% 0.54% 8.10%
Transmission and distribution costs. 4.41% 8.53% 0.00% 5.58%
Taxes other than income taxes....... 4.17% 2.21% 4.62% 3.61%
Income taxes........................ 5.04% 2.57% (63.13%) 4.11%
--------- --------- --------- --------
Total non-fuel operating expenses... 51.63% 34.46% 122.24% 46.90%
--------- --------- --------- --------
Operating income.................... 15.15% 7.95% (101.63%) 12.69%
--------- --------- --------- --------
44
Year Ended December 31, 1999 Compared to Year Ended December 31, 1998
Electric Operations - Operating revenues grew $76.8 million (9.2%) for
the year to $912.0 million as a 32.9% improvement in wholesale electricity sales
volume was only partially offset by the implementation of a new rate order in
late July 1999 (which lowered rates by $18 million and will lower rates by $37
million annually based on expected customer growth). The Company delivered
wholesale (bulk) power of 11.17 million MWh of electricity this year compared to
8.78 million MWh delivered last year, an increase of 27.2%. Retail electricity
delivery was 6.8 million MWh compared to 6.7 million MWh delivered last year, a
1.5% improvement while revenues declined 2.6% as a result of the new rate order.
Revenue growth for both the retail and wholesale businesses was negatively
impacted by cooler temperatures in the southwest during the summer months and
the availability of abundant hydro power which competes with the Company's
wholesale business.
The gross margin, or operating revenues minus cost of energy, decreased
$27.6 million reflecting a decrease in gross margin as a percentage of revenues
of 8.3%. This decline reflects the rate reduction discussed above and higher
fuel and purchased power costs.
Administrative and general increased $7.9 million (10.4%) for the year.
This increase is due to Year 2000 ("Y2K") compliance costs (see "OTHER ISSUES
FACING THE COMPANY - THE YEAR 2000 ISSUE") and costs related to the Company's
implementation of its new customer billing system. In addition, the Company
increased its bad debt accrual throughout 1999 by $5.5 million as a result of a
significant increase in delinquent accounts due to system implementation
problems (see Implementation of New Billing System below for additional
discussion). These increases primarily occurred in the distribution business. As
a percentage of revenues, administrative and other remained relatively constant
at 9.2% and 9.1% for the years ended December 31, 1999 and 1998, respectively.
This is a result of a decrease in administrative and other, as a percentage of
revenues, in the generation and transmission businesses due to an increase in
costs for 1998 and 1999 allocated to the partners in a jointly-owned generation
plant following an audit of such costs.
Energy production costs decreased $10.2 million (6.8%) for the year.
These costs are generation related. The decrease is primarily due to reduced
nuclear fuel storage costs at PVNGS. In 1998, the Company recorded a charge of
$12.1 million for spent nuclear fuel at PVNGS as it was determined that
alternatives to the DOE storage and disposal facilities would be necessary due
to the DOE's failure to complete such facilities by 1998 as required by law. The
charge represents the cost of storage for spent fuel through 1998. As a
percentage of revenues, energy production costs decreased form 17.9% to 15.3%.
The decrease is due to cost control and the decreased nuclear fuel storage
costs.
Depreciation and amortization increased $2.7 million (3.95%) for the
year. The increase is due to pollution control improvements at certain
generation plants and the impact of a new customer billing system. As a result
of the additions, the Company revised its depreciation rates as required by the
PRC. Depreciation and amortization as a percentage of revenues decreased from
8.4% to 8.0% reflecting an increase in energy production without a corresponding
increase in plant additions.
45
Transmission and distribution costs decreased $1.1 million (3.4%) for
the year. As a percentage of revenues, transmission and distribution costs
decreased from 3.9% to 3.4%. These decreases were primarily the result of lower
maintenance costs due to the milder weather.
Gas Operations - Operating revenues declined $19.3 million (7.5%) for
the year to $236.7 million. This decline was driven by a 13.8% decline in the
average rate charges per decatherm due to weak gas prices and a mild winter
resulting in a 3.2% volume decrease to residential and commercial customers.
Price declines were partially offset by a 7.7% volume improvement, as
transportation volume posted double-digit growth of 10.3%.
The gross margin, or operating revenues minus cost of energy, increased
$2.6 million (2.2%). As a percentage of revenues, gross margin increased 4.9%.
These increases are due to lower gas costs.
Administrative and general increased $3.5 million (7.2%). This increase
is mainly due to Y2K compliance costs of $2.6 million and costs related to the
Company's implementation of its new customer billing system. In addition, the
Company increased its bad debt accrual throughout 1999 by $2.7 million, as a
result of a significant increase in delinquent accounts due to system
implementation problems (see Implementation of New Billing System below for
additional discussion). As a percentage of revenues, administrative and other
costs increased from 19.1% to 22.5% reflecting primarily the effects of lower
gas costs discussed above.
Depreciation and amortization increased $3.9 million (24.7%) for the
year. The increase is due to the impact of the new customer billing system. As a
result of the addition, the Company revised its depreciation rates as required
by the PRC. Depreciation and amortization, as a percentage of revenues,
increased from 6.2% to 8.4% reflecting the effects of lower gas costs discussed
above and plant additions.
Transmission and distribution expenses increased $3.9 million (16.1%) for
the year. The increase is primarily due to Y2K compliance costs (see "OTHER
ISSUES FACING THE COMPANY - THE YEAR 2000 ISSUE"). Transmission and distribution
expenses, as a percentage of revenues, increased from 9.5% to 11.9%, reflecting
the effects of lower gas costs discussed above and the Y2K compliance costs.
Other - Other includes the Company's unregulated businesses, including
Avistar and certain corporate functions. The unregulated businesses contributed
$8.9 million in revenues in 1999 compared to $1.3 million in 1998. Operating
loss for the unregulated businesses decreased from $5.8 million in 1998 to $4.6
million in 1999 reflecting their expansion.
Consolidated - Other income and deductions, net of taxes, increased $7.5
million for the year to $30.2 million due to the recording of interest income
from the PVNGS Capital Trust. In addition, other income included certain
one-time gains. The Company recognized $4.2 million of equity income from a
passive investment and a gain of $1.2 million as a result of closing down of
coal mining reclamation activities in an inactive subsidiary.
Net interest charges increased $7.5 million for the year to $70.7
million as a result of the issuance of $435 million in senior unsecured notes in
August 1998, which replaced first mortgage bonds with a lower interest rate, and
the issuance of pollution control revenue bonds of $11.5 million in October
1999. This was partially offset by the retirement of $31.6 million of senior
unsecured notes in June and August 1999 and a decrease in short-term debt
interest charges due to lower short-term borrowings in 1999.
46
The Company's consolidated income tax expense, before the cumulative
effect of accounting change and discontinued operations, was $42.3 million, a
decrease of $14 million for the year. The Company's income tax effective rate,
before the cumulative effect of accounting change and discontinued operations,
decreased from 37.2% to 34.7%. This decrease is primarily due to the favorable
tax treatment received on the equity income discussed above. The investment
income qualifies for the 80% dividends received deduction under Internal Revenue
Service regulations.
The Company's net earnings from continuing operations for the year ended
December 31, 1999, were $79.6 million compared to $95.1 million for the year
ended December 31, 1998. Earnings per share from continuing operations on a
diluted basis were $1.93 compared to $2.25 for the year ended December 31, 1998.
Diluted weighted average shares outstanding were 41.1 million and 42.1 million
in 1999 and 1998, respectively. The decrease reflects the common stock
repurchase program in 1999. The 1999 results were negatively impacted by the
electric rate reduction in the third quarter, increased fuel and purchased power
costs, a weak gas market and cooler weather in the West during the summer
months. In addition, costs related to Y2K compliance and the implementation of
the new customer billing system increased costs. This impact was partially
offset by the gains recorded in other income.
Discontinued Operations - In August 1998, the Company adopted a plan to
discontinue the natural gas trading operations of its Energy Services Business
Unit and completely discontinued these operations on December 31, 1998. Losses
from discontinued operations, net of taxes, for the year ended December 31,
1998, were $12.4 million, or $0.30 per common share. These losses did not recur
in 1999.
Cumulative Effect of a Change in Accounting Principle - Effective
January 1, 1999, the Company adopted EITF Issue No. 98-10. The effect of the
initial application of the new standard is reported as a cumulative effect of a
change in accounting principle. As a result, the Company recorded additional
earnings, net of taxes, of approximately $3.5 million, or $0.08 per common
share, to recognize the gain on net open physical electricity purchase and sales
commitments considered to be trading activities.
Year Ended December 31, 1998 Compared to Year Ended December 31, 1997
Electric Operations - Operating revenues grew $112.8 million (15.6%)
for the year to $835.2 million. The Company delivered wholesale (bulk) power of
8.8 million MWh of electricity this year compared to 6.9 million MWh delivered
last year, an increase of 27.5%. Retail electricity delivery was 6.7 million MWh
compared to 6.5 million MWh delivered last year, a 3.1% improvement. Retail
revenues increased 3.3%. Revenue growth for the wholesale business was
positively impacted by an unusually hot summer in Arizona and California.
The gross margin or operating revenues minus cost of energy increased
38.0 million; however, gross margin as a percentage of revenues decreased by
4.5%. This is the result of increased purchases for resale as wholesale power
marketing activities increased.
Administrative and general increased $7.7 million (11.2%) for the year as
a result of increased Y2K compliance costs and an increase in certain benefit
costs. As a percentage of revenues, administrative and other decreased from 9.5%
to 9.1%.
47
Energy production costs increased 10.8 million (7.8%) for the year as a
result of a charge of $12.1 million for spent nuclear fuel costs at PVNGS (See
"Year Ended December 31, 1999, compared to Year Ended December 31,
1998--Electric Operations"). These costs are generation related. As a percentage
of revenues, energy production costs decreased from 19.1% to 17.9%.
Depreciation and amortization increased 2.1 million (3.1%) for the year
as a result of utility plant improvements and the write-off of certain
unamortized computer software to depreciation and amortization expense.
Depreciation and amortization as a percentage of revenues decreased from 9.4% to
8.4%.
Transmission and distribution costs decreased $1.2 million (3.8%) for the
year as a result of lower maintenance costs. As a percentage of revenues,
transmission and distribution costs decreased from 4.1% to 3.9%.
Gas Operations - Operating revenues declined $38.8 million (13.2%) for
the year to $256.0 million. This decline was driven by a 13.8% decline in the
average rate charges per decatherm. Total gas throughput volume increased 1.3%,
while residential and commercial volume decreased 1.5%.
The gross margin or operating revenues minus cost of energy decreased
$3.8 million (3.0%) as a result of warmer weather conditions in 1998. As a
percentage of revenues, gross margin increased 4.9%.
Administrative and general increased $1.5 million (3.2%) for the year as
a result of increased Y2K compliance costs and an increase in certain benefits
costs. As a percentage of revenues, administrative and other costs increased
from 16.1% to 19.1%.
Depreciation and amortization increased $1.0 million (6.7%) for the year
as a result of the write-off of certain retired plant assets to depreciation and
amortization expense. Depreciation and amortization, as a percentage of
revenues, increased from 5.0% to 6.2%.
Transmission and distribution expenses decreased $0.8 million (3.2%) for
the year as a result of higher maintenance costs in 1997 for items that did not
reoccur in 1998. Transmission and distribution expenses, as a percentage of
revenues, increased form 8.5% to 9.5%.
Other - Other includes the Company's unregulated business, which were
incorporated as Avistar in 1999, and certain corporate functions. The
unregulated businesses contributed $1.3 million in revenues in 1998 compared to
$3.3 million in 1997. Operating loss for the unregulated businesses increased
from $3.3 million in 1997 to $5.8 million in 1998. The remaining costs represent
corporate administrative costs.
Consolidated - Net other income and deductions increased $9.5 million
over a year ago as a result of the investment income, proceeds from a litigation
settlement and the reversal of a gas rate case reserve.
Net interest charges increased $7.0 million in 1998 due to the issuance
of $435 million of SUNs and increased short-term borrowings for the retirement
of $140 million of first mortgage bonds.
The Company's consolidated income tax expense, before discontinued
operations, was $56.3 million, an increase of $6.0 million for the year. The
Company's income tax effective rate, before discontinued operations, increased
from 36.8% to 37.2%.
48
The Company's net earnings from continuing operations for the year ended
December 31, 1998, were $95.1 million compared to $86.5 million for the year
ended December 31, 1997. Earnings per share from continuing operations on a
diluted basis were $2.25 compared to $2.05 for the year ended December 31, 1997.
Diluted weighted average shares outstanding were 42.1 million and 42.0 million
in 1998 and 1997, respectively.
Discontinued Operations - In August 1998, the Company adopted a plan to
discontinue the natural gas trading operations of its Energy Services Business
Unit and completely discontinued these operations on December 31, 1998. Losses
from discontinued operations, net of taxes, for the year ended December 31,
1998, were $12.4 million, including a charge of $5.1 million for estimated loss
on disposal, compared to $5.5 million in 1997. Loss per share, net of tax
benefit, on a diluted basis for the discontinued operations was $0.30 and $0.13
for 1998 and 1997, respectively.
LIQUIDITY AND CAPITAL RESOURCES
At December 31, 1999, the Company had working capital of $167 million
including cash and cash equivalents of $120.4 million. This is an increase in
working capital of $87.8 million. This increase is primarily the result of an
increase in cash and cash equivalents of $59.1 million and a reduction in
short-term debt of $26.6 million, partially offset by an increase in accounts
payable, reflecting higher year-over-year business levels.
Cash generated from operating activities was $214.5 million, an increase
of $3.5 million from 1998. This increase was offset by an increase in accounts
receivable of $30.2 million due to billing problems associated with the new
customer billing system (see Implementation of New Billing System below).
Cash used for investing activities was $55.9 million in 1999 compared
to $340.1 million in 1998. This decreased spending reflects lower construction
expenditures in 1999 of $32.3 million and the liquidation of insurance-based
investments in the nuclear decommissioning trust of $26.6 million (see financing
activities for the payment of decommissioning debt of $26.6 million). In
addition, in 1998, the Company purchased $215.7 million of debt underlying
certain of its leases of PVNGS.
Cash used for financing activities was $99.5 million in 1999. This
increase is the result of the repurchase of $31.6 million of senior unsecured
notes, $26.6 million of loan repayments associated with nuclear decommissioning
trust activities and an $18.8 million stock repurchase by the Company. Cash
provided from financing activities in 1998 was $173 million and included
proceeds from the issuance of senior unsecured notes of $435 million and
repayment of short-term borrowings of $231.3 million.
49
Capital Requirements
Total capital requirements include construction expenditures as well as
other major capital requirements and cash dividend requirements for both common
and preferred stock. The main focus of the Company's construction program is
upgrading generating systems, upgrading and expanding the electric and gas
transmission and distribution systems and purchasing nuclear fuel. Projections
for total capital requirements and construction expenditures for 2000 are $250.9
million and $219.1 million, respectively. Such projections for the years 2000
through 2004 are $1.2 billion and $1.1 billion, respectively. These estimates
are under continuing review and subject to on-going adjustment (see Competitive
Strategy above).
The Company's construction expenditures for 1999 were entirely funded
through cash generated from operations. The Company currently anticipates that
internal cash generation and current debt capacity will be sufficient to meet
capital requirements for the years 2000 through 2004. To cover the difference in
the amounts and timing of cash generation and cash requirements, the Company
intends to use short-term borrowings under its liquidity arrangements.
Liquidity
At the end of February 2000, the Company had $175 million of available
liquidity arrangements, consisting of $150 million from a senior unsecured
revolving credit facility ("Credit Facility"), and $25 million in local lines of
credit. The Credit Facility will expire in March 2003. There were no outstanding
borrowings as of February 29, 2000.
The Company's ability to finance its construction program at a
reasonable cost and to provide for other capital needs is largely dependent upon
its ability to earn a fair return on equity, results of operations, credit
ratings, regulatory approvals and financial market conditions. Financing
flexibility is enhanced by providing a high percentage of total capital
requirements from internal sources and having the ability, if necessary, to
issue long-term securities, and to obtain short-term credit.
On August 26, 1999, two major credit rating agencies, Moody's Investors
Services, Inc. ("Moody's") and Standard and Poor's Corp. ("S&P") upgraded the
Company's securities following the rate order by the PRC (see "OTHER ISSUES
FACING ATHE COMPANY - Electric Rate Case" below). The Company's rating outlook
by both rating agencies is "stable". Moody's upgrades include the Company's
senior unsecured notes and senior unsecured pollution control revenue bonds to
"Baa3" from "Ba1"; and preferred stock to "ba1" from "b1". The EIP lease
obligation bonds were also upgraded to "Ba1" from "Ba2". S&P also upgraded,
among other things, the Company's senior unsecured debt and bank loan credit
rating to BBB- from BB+. Investors are cautioned that a security rating is not a
recommendation to buy, sell or hold securities, that it may be subject to
revision or withdrawal at any time by the assigning rating organization, and
that each rating should be evaluated independently of any other rating.
These rating actions reflect the resolution of the Company's litigious
electric rate case that began in 1997 and the passage of the Restructuring Act
(see "Overview" above) that allows utilities to recover no less than fifty
percent of their stranded costs. If certain conditions identified in the state
law are met, utilities may be allowed recovery of up to one hundred percent of
stranded costs. The rating agencies believe that the combination of these two
events reduces a large component of regulatory and legislative uncertainty,
which collectively help to support the Company's long-term prospects for
maintaining cash flow and earning stability. Future rating actions for the
Company's securities will depend in large part on the filing with the PRC
relating to numerous restructuring issues, including the Company's plan to
separate the utility into a generation business and a distribution and
transmission business as required by the recently enacted state law. The Company
is required to file a transition plan with the PRC by June 1, 2000.
50
Covenants in the Company's PVNGS Units 1 and 2 lease agreements (see PART
I, ITEM 2. - "PROPERTIES - Nuclear Plant") limit the Company's ability, without
consent of the owner participants in the lease transactions: (i) to enter into
any merger or consolidation, or (ii) except in connection with normal dividend
policy, to convey, transfer, lease or dividend more than 5% of its assets in any
single transaction or series of related transactions. The Credit Facility
imposes similar restrictions regardless of credit ratings.
Financing Activities
In 1999, the Company retired $31.6 million of its 7.1% senior unsecured
notes through open market purchases, utilizing the funds from operations and the
funds from temporary investments. In January 2000, the Company reacquired $35.0
million of its 7.5% senior unsecured notes through open market purchases. On
October 28, 1999, tax-exempt pollution control revenue bonds of $11.5 million
with an interest rate of 6.60% were issued to partially reimburse the Company
for expenditures associated with its share of a recently completed upgrade of
the emission control system at SJGS.
The Company currently has no requirements for long-term financings during
the period of 2000 through 2004 except as part of its implementation of its
holding company plan. However, during this period, the Company could enter into
long-term financings for the purpose of strengthening its balance sheet and
reducing its cost of capital. The Company continues to evaluate its investment
and debt retirement options to optimize its financing strategy and earnings
potential. No additional first mortgage bonds may be issued under the Company's
mortgage. The amount of SUNs that may be issued is not limited by the SUNs
indenture. However, debt to capital requirements in certain of the Company's
financial instruments would ultimately restrict the Company's ability to issue
SUNs.
Implementation of the Company's holding company plan will not result in
any change in the consolidated outstanding indebtedness of the Company. In
connection with the transfer of the regulated business by the Company to
UtilityCo and the permanent debt financing for the assets to be transferred,
subject to the receipt of the necessary regulatory and other approvals,
UtilityCo may make an offer to holders of the Company's public senior unsecured
notes ($403 million outstanding as of December 31, 1999) to exchange these notes
for newly-issued senior unsecured notes of UtilityCo with substantially the same
terms as the existing notes. Alternatively, some or all of these notes could
continue to be equity securities of Energy depending on the results of any
exchange offer or if it is more appropriate to capitalize UtilityCo with newly
issued debt and use the proceeds from this debt issue to purchase a portion of
the assets to be transferred to UtilityCo from Energy. It is currently planned
that $586 million of currently outstanding pollution control revenue bonds
(secured by senior unsecured notes and first mortgage bonds) will remain as a
debt obligation of Energy after the share exchange and corporation separation
since these bonds were issued to finance the ownership and operation of electric
generation assets.
The Company's preferred stock ($12.8 million outstanding as of December
31, 1999), will remain an equity security of Energy after the share exchange
unless an exchange offer is made by UtilityCo and accepted by all holders or the
preferred stock is redeemed by the Company. Depending on the results of any
exchange for the Company's preferred stock, some or all of the preferred stock
could remain an equity security of Energy or become a new equity security of
UtilityCo.
51
Stock Repurchase
In March 1999, the Company's board of directors approved a plan to
repurchase up to 1,587,000 shares of the Company's outstanding common stock with
maximum purchase price of $19.00 per share. In December 1999, the Company's
board of directors authorized the Company to repurchase up to an additional
$20.0 million of the Company's common stock. As of December 31, 1999, the
Company repurchased 1,070,700 shares of its previously outstanding common stock
at a cost of $18.8 million. From January 2, 2000 through February 29, 2000, the
Company repurchased an additional 963,284 shares of its outstanding common stock
at a cost of $15.7 million. The Company may from time-to-time repurchase
additional common stock for various corporate purposes.
Dividends
The Company resumed the payment of cash dividends on common stock in May
1996. The Company's board of directors reviews the Company's dividend policy on
a continuing basis. The payment of future dividends will depend on a number of
factors, including the extent to which cash flows will support dividends, the
availability of retained earnings, the financial circumstances and performance
of the Company, the PRC's decisions on the Company's various regulatory cases
currently pending, the effect of deregulating generation markets and market
economic conditions generally. In addition, the ability to recover stranded
costs in deregulation, future growth plans and the related capital requirements
and standard business considerations will also affect the Company's ability to
pay dividends.
Capital Structure
The Company's capitalization, including current maturities of long-term
debt, at December 31 is shown below:
1999 1998
---- ----
Common Equity.............................. 46.7% 45.4%
Preferred Stock............................ 0.7 0.7
Long-term Debt............................. 52.6 53.9
----- -----
Total Capitalization*................... 100.0% 100.0%
===== =====
*Total capitalization does not include as debt the present value ($161
million as of December 31, 1999) of the Company's lease obligations
for PVNGS Units 1 and 2 and EIP.
52
OTHER ISSUES FACING THE COMPANY
THE RESTRUCTURING ACT AND THE FORMATION OF HOLDING COMPANY
The Restructuring Act requires that assets and activities subject to the
PRC jurisdiction, primarily electric and gas distribution, and transmission
assets and activities (collectively, the "Regulated Business"), be separated
from other competitive business, primarily electric generation and service and
certain other energy services (collectively, "the Deregulated Competitive
Businesses"). Such separation is required to be accomplished through the
creation of at least two separate corporations. The Company has decided to
accomplish the mandated separation by the formation of a holding company and the
transfer of the Regulated Businesses to a newly-created, wholly owned subsidiary
of the holding company, subject to various regulatory approvals. The holding
company structure is expressly authorized by the Restructuring Act. Corporate
separation of the Regulated Business from the Deregulated Competitive Businesses
must be completed by January 1, 2001, although the date may be extended by up
to one year by the PRC. Completion of corporate separation will require a number
of regulatory approvals by, among others, the PRC and the Nuclear Regulatory
Commission.
Completion will also require shareholder approval and a number of other
consents from creditors and lessors. Completion may also entail significant
restructuring activities with respect to the Company's existing liquidity
arrangements and the Company's publicly-held senior unsecured notes of which
$403.4 million were outstanding as of December 31, 1999. Holders of the
Company's senior unsecured notes, $135 million at 7.5% and $268.4 million at
7.1%, may be offered the opportunity to exchange their securities for similar
senior unsecured notes of the newly created regulated business (see "Liquidity
and Capital Resources - Financing Activities" above).
Regulated Business
The Regulated Business comprised approximately 47.9% of the Company's
total assets and contributed approximately 39.6% of the Company's operating
revenues and approximately 61.1% of the Company's operating income before
interest charges in 1999.
Stranded Costs
The Restructuring Act recognizes that electric utilities should be
permitted a reasonable opportunity to recover an appropriate amount of the costs
incurred previously in providing electric service ("stranded costs"). Stranded
costs include plant decommissioning costs, regulatory assets, lease and
lease-related costs recognized under cost-of-service regulation. Utilities will
be allowed to recover no less than 50% of such costs through a non-bypassable
charge on all customer bills for five years after implementation of customer
choice. The PRC could authorize a utility to recover up to 100% of its stranded
costs if the PRC finds that recovery of more than 50%: (i) is in the public
interest; (ii) is necessary to maintain the financial integrity of the public
utility; (iii) is necessary to continue adequate and reliable service; and (iv)
will not cause an increase in rates to residential or small business customers
during the transition period. While recoverable stranded costs will be collected
as part of the regulated business, it is anticipated that such collections would
be paid to the Company and be part of the revenues available to the competitive
businesses subsequent to restructuring. However, no determination and
quantification of stranded cost recovery has yet been made by the PRC. Such
determination will have a material impact on the consolidated financial results
and position of the Company.
53
Transition Cost Recovery
Pursuant to the Restructuring Act, utilities will also be allowed to
recover in full any prudent and reasonable costs incurred in implementing full
open access ("transition costs"). The transition costs will be recovered through
2007 by means of a separate wires charge. The Company estimates that these costs
will be in excess of $50 million. Transition costs include, but are not limited
to, professional fees, financing costs including underwriting fees, consents
relating to the transfer to assets, management information system changes
including billing system changes and public and customer education and
communications. Recoverable transition costs are currently being capitalized and
will be amortized over the recovery period to match related revenues. Recovery
of any transition costs, which are not deemed recoverable by the PRC, may be
vigorously pursued through all remedies available to the Company with the
ultimate outcome uncertain. Costs not recoverable will be expensed when incurred
unless these costs are otherwise permitted to be capitalized under current and
future accounting rules. If the amount of nonrecoverable transition costs is
material, the resulting charge to earnings may have a material impact on the
consolidated financial results and position of the Company.
Deregulated Competitive Businesses
The Deregulated Competitive Businesses which would be retained by the
Company include the Company's interests in generation facilities, including
PVNGS, Four Corners, and SJGS, together with the pollution control facilities
which have been financed with pollution control revenue bonds. Approximately
$586 million in pollution control revenue bonds would remain as obligations of
the generation subsidiary, as would certain other of the Company's long-term
obligations. The Deregulated Competitive Businesses would not be subject to
regulation by the PRC. Under the Company's restructuring plan, the Company's
bondholders will continue to hold obligations of the Company following
restructuring. Since the Restructuring Act requires significant changes in the
assets and businesses of the Company, the bondholders will be accepting the
risks involved in those changes.
The Company will continue its Deregulated Competitive Business following
the restructuring, which will be subject to market conditions. Following the
separation as required by the Restructuring Act, in support of its wholesale
trading operations, the Company is targeting to double its generating capacity
and triple its sales volume. Recently, the Company formed a non-regulated
subsidiary, Avistar, in August 1999, to implement competitive business
strategies. Avistar provides services in the areas of utility management for
municipalities and other communities, remote metering and development of energy
conservation and supply projects for federal government facilities. The Company
does not anticipate an earnings contribution from Avistar over the next few
years.
NRC Prefunding
Pursuant to NRC rules on financial assurance requirements for the
decommissioning of nuclear power plant, the Company has a program for funding
its share of decommissioning costs for PVNGS through a sinking fund mechanism
(see PART I - ITEM 2. PROPERTIES - ELECTRIC - Nuclear Plant - PVNGS
Decommissioning Funding"). The NRC rules on financial assurance became effective
on November 23, 1998. The amended rules provide that a licensee may use an
external sinking fund as the exclusive financial assurance mechanism if the
licensee recovers estimated decommissioning costs through cost of service rates
or a "non-bypassable charge". Other mechanisms are prescribed, such as
prepayment, surety methods, insurance and other guarantees, to the extent that
the requirements for exclusive reliance on the fund mechanism are not met.
The Restructuring Act allows for the recoverability of 50% up to 100%
of stranded costs including decommissioning costs (see "Stranded Costs"). If the
Company is unable to meet the requirements of the NRC rules permitting the use
of an external sinking fund because it is unable to recover all of its estimated
decommissioning costs through a non-bypassable charge, the Company may have to
pre-fund or find a similarly capital intensive means to meet the NRC rules.
There can be no assurance that such an event will not negatively affect the
funding of the Company's growth plans.
54
In addition, as part of the determination and quantification of the
stranded costs related to the decommissioning, the Company will have to estimate
future decommissioning costs. If the Company's estimate proves to be less than
the actual costs of decommissioning, any cost in excess of the amount allowed
through stranded cost recovery may not be recoverable. Such excess costs, if
any, will also be subject to the pre-funding requirements discussed above.
Competition
Under current law, PNM is not in any direct retail competition with any
other regulated electric and gas utility. Nevertheless, PNM is subject to
varying degrees of competition in certain territories adjacent to or within
areas it serves that are also currently served by other utilities in its region
as well as cooperatives, municipalities, electric districts and similar types of
government organizations.
The Restructuring Act opens the state's electric power market to
customer choice for certain customers beginning in 2001 and the balance of
customers in 2002. As a result, the Company may face competition from companies
with greater financial and other resources. There can be no assurance that the
Company will not face competition in the future that would adversely affect its
results.
It is the current intention to have the Company's Deregulated
Competitive Businesses engage primarily in energy-related businesses that will
not be regulated by state or Federal agencies that currently regulate public
utilities (other than the FERC and NRC). These competitive businesses, including
the generation business, will encounter competition and other factors not
previously experienced by the Company, and may have different, and perhaps
greater, investment risks than those involved in the regulated business that
will be engaged in by the Regulated Businesses. Specifically, the passage of the
Restructuring Act and deregulation in the electric utility industry generally is
likely to have an impact on the price and margins for electric generation and
thus, the return on the investment in electric generation assets. In response to
competition and the need to gain economies of scale, electricity producers will
need to control costs to maintain margins, profitability and cash flow that will
be adequate to support investments in new technology and infrastructure. The
Company will have to compete directly with independent power producers, many of
whom will be larger in scale, thus creating a competitive advantage for such
producers due to scale efficiencies. The Company's current five year business
plan includes a 300% increase in sales and through doubling the construction or
acquisition of additional power generation assets in its surrounding region of
operations. Such growth will be dependent upon the Company's ability to generate
$400 to $600 million to fund the deregulated competitive expansion. There can be
no assurance that these Deregulated Competitive Businesses, particularly the
generation business, will be successful or, if unsuccessful, that they will not
have a direct or indirect adverse effect on the Company.
IMPLEMENTATION OF NEW BILLING SYSTEM
On November 30, 1998, the Company implemented a new customer billing
system. Due to a significant number of problems associated with the
implementation of the new billing system, the Company was unable to generate
appropriate bills for all its customers through the first quarter of 1999 and
was unable to analyze delinquent accounts until November 1999.
55
Under PRC rules and PRC approved Company rules, the Company is required
to issue customer bills on a monthly basis. The Company was granted a temporary
variance, and the PRC began a hearing on whether the Company violated PRC rules,
regulations or orders or the New Mexico Public Utility Act. The investigation
was concluded on November 2, 1999, without the PRC imposing any civil penalty on
the Company and with an approved stipulation that the Company be permitted to
bill an additional service charge to customers who were not billed the
appropriate electric service charge and/or gas access fee. The stipulation was
limited to approximately $0.7 million in the November and December billing
cycles.
Because of the implementation issues associated with the new billing
system, the Company estimated retail gas and electric revenues through July
1999. Beginning with August 1999, the Company was able to determine actual
revenues for all prior periods affected and began reconciling with previously
estimated revenues. In December 1999, the Company completed its reconciliation
of system revenues. As a result, 1999 revenues represented actual revenues as
determined by the new billing system. The resulting reconciliation did not
materially impact recorded revenues. However, a significant number of individual
accounts required corrections.
As a result of the delay of normal collection activities, the Company
incurred a significant increase in delinquent accounts, many of which occurred
with customers that no longer have active accounts with the Company. As a
result, the Company significantly increased its bad debt accrual throughout
1999.
The following is a summary of the allowance for doubtful accounts during
1999, 1998 and 1997:
1999 1998 1997
-------- ------- -------
(In thousands)
Allowance for doubtful accounts beginning
of year......................................... $ 836 $ 783 $ 709
Bad debt accrual.................................. 11,496 3,325 3,378
Less: Write off (adjustments) of
uncollectible accounts .................... (172) 3,272 3,304
-------- ------- -------
Allowance for doubtful accounts, end of year ..... $12,504 $ 836 $ 783
======== ======= =======
ELECTRIC RATE CASE
In November 1998, the NMPUC issued a final order in the Company's
electric rate case, requiring the Company to reduce rates in 1999 by $60.2
million, by $25.6 million in 2000 and by an additional $25.6 million in 2001.
The rate reduction order reflected, among other things, the revaluation of the
Company's generation resources based on a so-called "market-based price" and the
finding by the NMPUC that recovery of stranded costs is illegal. In December
1998, the Company appealed the rate case order to the New Mexico Supreme Court
("Supreme Court").
56
On March 15, 1999, the Supreme Court issued a ruling, vacating the NMPUC
order on the Company's electric rate case and remanding the case to the PRC, the
successor of the NMPUC, for further proceedings.
On August 25, 1999, the PRC issued an order approving a settlement. The
PRC ordered the Company to reduce its electric rates by $34.0 million
retroactive to July 30, 1999. In addition, the order includes a rate freeze
until retail electric competition is fully implemented in New Mexico or until
January 1, 2003. The settlement will reduce annual revenues by an estimated
$37.0 million based on expected customer growth and will reduce electric
distribution operating revenues in the year 2000 by approximately $20 million.
As part of the settlement, the Company agreed that certain language
changes to the tariff KAFB currently takes service under be set for a separate
hearing before the PRC. Hearings on this issue have not yet been scheduled. KAFB
has not renewed its power service contract with the Company that expired in
December 1999 (see ITEM 3. - "LEGAL PROCEEDINGS - OTHER PROCEEDINGS - Kirtland
Air Force Base ("KAFB") Contract").
EFFECTS OF CERTAIN PENDING EVENTS ON FUTURE REVENUES
The Company's contract with SDG&E to provide electricity will expire in
April of 2001. SDG&E has notified the Company that it will not renew its
contract. The Company currently estimates that the net revenue reduction
resulting from the expiration of the SDG&E contract will be approximately $20
million annually. In addition, there is currently ongoing litigation between the
Company and SDG&E regarding prior years' contract pricing.
On October 4, 1999, Western, filed a petition at the FERC requesting the
FERC to consider, on an expedited basis, ordering the Company to provide network
transmission service to Western under the Company's Open Access Transmission
Tariff on behalf of the DOE as contracting agent for KAFB. The Company intends
to litigate this matter vigorously. The net revenue reduction to the Company if
the Company is replaced as the power supplier to KAFB is estimated to be
approximately $7.0 million annually.
A further discussion of these and other legal proceedings can be found
in PART I, ITEM 3. - "LEGAL PROCEEDINGS" in this Annual Report on Form 10-K.
THE YEAR 2000 ISSUE
The Company experienced no year 2000 failures of its electric generation
or its gas and electric distribution and transmission systems during the
critical year 2000 transition period. Further, the Company has experienced no
failures in any of these systems in the ensuing period. As a result, no
customers experienced a year 2000 related disruption to their gas or electric
service.
The Company anticipates that minor, previously undetected, programming
issues might surface during the year 2000. These are not expected to impact the
Company's customers.
During 1999, the Company expended $15.3 million on the Year 2000 Project
for a total expenditure of $20.7 million through the end of 1999. The Company
expects to spend approximately $175 thousand in 2000 on efforts to finalize
project documentation and to file reports with various regulatory agencies.
57
COAL FUEL SUPPLY
The coal requirements for the SJGS are being supplied by SJCC, a wholly
owned subsidiary of BHP, from certain Federal, state and private coal leases
under a Coal Sales Agreement, pursuant to which SJCC will supply processed coal
for operation of the SJGS until 2017. The primary sources of coal for current
operations are a mine adjacent to the SJGS and a mine located approximately 25
miles northeast of the SJGS in the La Plata area of northwestern New Mexico.
Additional coal resources will be required. The Company is currently in
discussions regarding alternatives.
In 1997, the Company was notified by SJCC of certain audit exceptions
identified by the Federal Minerals Management Service ("MMS") for the period
1986 through 1997. These exceptions pertain to the valuation of coal for
purposes of calculating the Federal coal royalty. Primary issues include whether
coal processing and transportation costs should be included in the base value of
La Plata coal for royalty determination. Administrative appeals of the MMS
claims are pending.
The Company was notified during the fourth quarter of 1998 that the MMS
agreed to a mediation of the claims. It is the Company's understanding that the
mediation has not yet occurred. The Company is unable to predict the outcome of
this matter and the Company's exposures have not yet been assessed.
In 1996, the Company was notified by SJCC that the Navajo Nation has
proposed to select certain properties within the San Juan and La Plata Mines
(the "mining properties") pursuant to the Navajo-Hopi Land Settlement Act of
1974 (the "Act"). The mining properties are operated by SJCC under leases from
the BLM and comprise a portion of the fuel supply for the SJGS. An
administrative appeal by SJCC is pending. In the appeal, SJCC expressed concern
that transfer of the mining properties to the Navajo Nation may subject the
mining operations to taxation and additional regulation by the Navajo Nation,
both of which could increase the price of coal that might potentially be passed
on to the SJGS through the existing coal sales agreement. The Company is
monitoring the appeal and other developments on this issue and will continue to
assess potential impacts to the SJGS and the Company's operations. The Company
is unable to predict the ultimate outcome of this matter.
FUEL, WATER AND GAS NECESSARY FOR GENERATION OF ELECTRICITY
The Company's generation mix for 1999 was 69.0% coal, 30.0% nuclear and
1.0% gas and oil. Due to locally available natural gas and oil supplies, the
utilization of locally available coal deposits and the generally abundant supply
of nuclear fuel, the Company believes that adequate sources of fuel are
available for its generating stations (see "COAL FUEL SUPPLY" above).
58
Water for Four Corners and SJGS is obtained from the San Juan River. BHP
holds rights to San Juan River water and has committed a portion of such rights
to Four Corners through the life of the project. The Company and Tucson have a
contract with the USBR for consumption of 16,200 acre feet of water per year for
the SJGS, which contract expires in 2005. In addition, the Company was granted
the authority to consume 8,000 acre feet of water per year under a state permit
that is held by BHP. The Company is of the opinion that sufficient water is
under contract for the SJGS through 2005. Currently, the Company is in
discussions with the Jicarilla Apache Tribe for a twenty-seven year contract,
beginning in 2006, for a replacement of the current USBR contract for 16,200 AF
of water. The Company cannot predict the outcome of these discussions but
expects to obtain a replacement water supply for the USBR contract that expires
in 2005. Various environmental approvals will likely be required for a
replacement water supply. The Company is actively involved in the San Juan River
Recovery Implementation Program to mitigate any concerns with the taking of the
negotiated water supply from a river that contains endangered species and
critical habitat. As a result, the Company believes that adequate sources of
water are available for its generating stations.
PNMGS obtains its supply of natural gas primarily from sources within
New Mexico pursuant to contracts with producers and marketers. These contracts
are generally sufficient to meet PNMGS' peak-day demand. PNMGS serves certain
cities which depend on EPNG or Transwestern Pipeline Company for transportation
of gas supplies. Because these cities are not directly connected to PNMGS'
transmission facilities, gas transported by these companies is the sole supply
source for those cities. The Company believes that adequate sources of gas are
available for its distribution systems.
COMPLIANCE WITH ENVIRONMENTAL LAWS AND REGULATIONS
The Company's operations are subject to various federal, state, local
and tribal environmental laws and regulations, including, but not limited to,
those governing discharges into the air and water, the storage, handling and
disposal of solid and hazardous wastes, the remediation of soil and groundwater
contaminated by hazardous substances or wastes, and the health and safety of
employees particularly as it relates to the Company's coal, gas and nuclear
based electric generation assets. Compliance with environmental laws, stricter
interpretations of or amendments to such laws, or more vigorous enforcement
policies by regulatory agencies may require material expenditures by the
Company. The nature of the Company's current and former operations and the
history of industrial uses at some of its facilities result in exposure to the
risk of liabilities or claims with respect to environmental and worker health
and safety matters. In addition, under certain environmental laws, a current or
previous owner or operator of property may be jointly and severally liable for
the costs of investigation, removal or remediation of certain substances on,
under, or in such property, without regard to negligence or fault. The presence
of, or failure to remediate properly, such substances may adversely affect the
ability to sell or rent such property or to borrow using such property as
collateral. In addition, persons who generate, arrange for the disposal or
treatment of, or dispose of, hazardous substances may be jointly and severally
liable for the costs of investigation, remediation or removal of such hazardous
substances at or from the disposal or treatment facility, regardless of whether
the facility is owned or operated by such person. Responsible parties also may
be subject to common law claims by third parties based on damages and costs
resulting from environmental contamination emanating from a site.
59
Labor Union Negotiations
The Company and the International Brotherhood of Electrical Workers
("IBEW") Local Union 611 will enter into negotiations for a successor agreement
during the later part of the first quarter of 2000. The current collective
bargaining agreement, which covers the 654 bargaining unit employees in the
Company's regulated operations, expires on May 1, 2000. The Company's
negotiating team is currently preparing for the upcoming negotiations. While the
Company believes that its relations with its employees are satisfactory, a
dispute between the Company and its employees' representative could have a
material adverse effect on the Company.
Navajo Nation Tax Issues
APS, the operating agent for Four Corners, has informed the Company that
in March 1999, APS initiated discussions with the Navajo Nation regarding
various tax issues in conjunction with the expiration of a tax waiver, in July
2001, which was granted by the Navajo Nation in 1985. The tax waiver pertains to
the possessory interest tax and the business activity tax associated with the
Four Corners operations on the reservation. The Company believes that the
resolution of these tax issues will require an extended process and could
potentially affect the cost of conducting business activities on the
reservation. The Company is unable to predict the ultimate outcome of
discussions with Navajo Nation regarding these tax issues.
NEW AND PROPOSED ACCOUNTING STANDARDS
Decommissioning: The Staff of the Securities and Exchange Commission
("SEC") has questioned certain of the current accounting practices of the
electric industry regarding the recognition, measurement and classification of
decommissioning costs for nuclear generating stations in financial statements of
electric utilities. In response to these questions, the FASB has a project on
its agenda to review the accounting for closure and removal costs, including
decommissioning of nuclear power plants. If current electric industry accounting
practices for nuclear power plant decommissioning are changed, the estimated
cost for decommissioning could be recorded as a liability with recognition of an
increase in the cost of the related nuclear power plant. The Company does not
believe that such changes, if required, would have a material adverse effect on
results of operations.
EITF Issue 99-14, Recognition of Impairment Losses on Firmly Committed
Executory Contracts: The Emerging Issues Task Force ("EITF") has added an issue
to its agenda to address impairment of leased assets. A significant portion of
the Company's nuclear generating assets are held under operating leases. Based
on the alternative accounting methods being explored by the EITF, the related
financial impact of the future adoption of EITF Issue No. 99-14 should not have
a material adverse effect on results of operations. However, a complete
evaluation of the financial impact from the future adoption of EITF Issue No.
99-14 will be undeterminable until EITF deliberations are completed and stranded
cost recovery issues are resolved.
60
Accounting for Derivative Instruments and Hedging Activities, SFAS 133:
SFAS 133 establishes accounting and reporting standards requiring that every
derivative instrument be recorded in the balance sheet as either an asset or
liability measured at its fair value. The Statement also requires that changes
in the derivatives' fair value be recognized currently in earnings unless
specific hedge accounting criteria are met. Special accounting for qualifying
hedges allows derivative gains and losses to offset related results on the
hedged item in the income statement, and requires that a company must formally
document, designate, and assess the effectiveness of transactions that receive
hedge accounting. The Company is in the process of reviewing and identifying all
financial instruments currently existing in the Company in compliance with the
provisions of SFAS 133. It is likely that the adoption of SFAS 133 will add
volatility to the Company's operating results and/or asset and liability
valuations reflecting the impact of mark-to-market accounting for commodity
contracts. In June 1999, Financial Accounting Standards Board ("FASB") issued
SFAS 137 to amend the effective date for the compliance of SFAS 133 to January
1, 2001.
DISCLOSURE REGARDING FORWARD LOOKING STATEMENTS
The Private Securities Litigation Reform Act of 1995 (the "Act") provides
a "safe harbor" for forward-looking statements to encourage companies to provide
prospective information about their companies without fear of litigation so long
as those statements are identified as forward-looking and are accompanied by
meaningful, cautionary statements identifying important factors that could cause
actual results to differ materially from those projected in the statement. Words
such as "estimates," "expects," "anticipates," "plans," "believes," "projects,"
and similar expressions identify forward-looking statements. Accordingly, the
Company hereby identifies the following important factors which could cause the
Company's actual financial results to differ materially from any such results
which might be projected, forecasted, estimated or budgeted by the Company in
forward-looking statements: (i) adverse actions of utility regulatory
commissions; (ii) utility industry restructuring; (iii) failure to recover
stranded costs; (iv) the inability of the Company to successfully compete
outside its traditional regulated market; (v) regional economic conditions,
which could affect customer growth; (vi) adverse impacts resulting from
environmental regulations; (vii) loss of favorable fuel supply contracts or
inability to negotiate new fuel supply contracts; (viii) failure to obtain water
rights and rights-of-way; (ix) operational and environmental problems at
generating stations; (x) the cost of debt and equity capital; (xi) weather
conditions; and (xii) technical developments in the utility industry.
61
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK
The Company uses derivative financial instruments in limited instances
to manage risk as it relates to changes in natural gas and electric prices and
adverse market changes for investments held by the Company's various trusts. The
Company is exposed to credit losses in the event of non-performance or
non-payment by counterparties. The Company uses a credit management process to
assess and monitor the financial conditions of counterparties. The Company also
uses, on a limited basis, certain derivative instruments for bulk power
electricity trading purposes in order to take advantage of favorable price
movements and market timing activities in the wholesale power markets.
Information about market risk is set forth in Note 5 to the Notes to the
Consolidated Financial Statements and incorporated by reference. The following
additional information is provided.
The Company uses value at risk ("VAR") to quantify the potential
exposure to market movement on its open contracts and excess generating assets.
The VAR is calculated utilizing the variance/co-variance methodology over a
three day period within a 99% confidence level.
The Company's VAR as of December 31, 1999 from its electric trading
contracts and gas purchase contracts was $2.4 million.
The VAR represents an estimate of the reasonably possible net losses
that would be recognized on the portfolio of derivatives assuming hypothetical
movements in future market rates, and is not necessarily indicative of actual
results that may occur, since actual future gains and losses will differ from
those estimated. Actual gains and losses may differ from estimates due to actual
fluctuations in market rates, operating exposures, and the timing thereof, as
well as changes to the portfolio of derivatives during the year.
62
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX
Page
----
Management's Responsibility for Financial Statements .................. F-1
Report of Independent Public Accountants .............................. F-2
Financial Statements:
Consolidated Statements of Earnings ................................ F-3
Consolidated Balance Sheets ........................................ F-4
Consolidated Statements of Cash Flows .............................. F-6
Consolidated Statements of Capitalization .......................... F-7
Notes to Consolidated Financial Statements ......................... F-8
Supplementary Data:
Quarterly Operating Results ........................................ F-42
Comparative Operating Statistics ................................... F-43
MANAGEMENT'S RESPONSIBILITY FOR FINANCIAL STATEMENTS
The accompanying financial statements, which consolidate the accounts of Public
Service Company of New Mexico and its subsidiaries, have been prepared in
conformity with generally accepted accounting principles.
The integrity and objectivity of data in these financial statements and
accompanying notes, including estimates and judgments related to matters not
concluded by year-end, are the responsibility of management as is all other
information in this Annual Report. Management devotes ongoing attention to
review and appraisal of its system of internal controls. This system is designed
to provide reasonable assurance, at an appropriate cost, that the Company's
assets are protected, that transactions and events are recorded properly and
that financial reports are reliable. The system is augmented by a staff of
corporate auditors; careful attention to selection and development of qualified
financial personnel; programs to further timely communication and monitoring of
policies, standards and delegated authorities; and evaluation by independent
auditors during their audits of the annual financial statements.
The Audit Committee of the Board of Directors, composed entirely of outside
directors, meets regularly with financial management, the corporate auditors and
the independent auditors to review the work of each. The independent auditors
and corporate auditors have free access to the Audit Committee, without
management representatives present, to discuss the results of their audits and
their comments on the adequacy of internal controls and the quality of financial
reporting.
F-1
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors and Stockholders of
Public Service Company of New Mexico:
We have audited the accompanying consolidated balance sheets and statements of
capitalization of Public Service Company of New Mexico (a New Mexico
Corporation) and subsidiaries as of December 31, 1999 and 1998, and the related
consolidated statements of earnings, comprehensive income, retained earnings and
cash flows for each of the three years in the period ended December 31, 1999.
These financial statements are the responsibility of the Company's management.
Our responsibility is to express an opinion on these financial statements based
on our audits.
We conducted our audits in accordance with auditing standards generally accepted
in the United States. 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, the financial statements referred to above present fairly, in
all material respects, the financial position of Public Service Company of New
Mexico and subsidiaries as of December 31, 1999 and 1998, and the results of its
operations and its cash flows for each of the three years in the period ended
December 31, 1999 in conformity with accounting principles generally accepted in
the United States.
ARTHUR ANDERSEN LLP
Albuquerque, New Mexico
January 26, 2000
F-2
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EARNINGS
-----------------------------------
Year Ended December 31,
-----------------------------------
1999 1998 1997
---------- ---------- ----------
(In thousands, except per share amounts)
Operating Revenues: (note 1, 7)
Electric................................................... $ 911,977 $ 835,204 $722,438
Gas........................................................ 236,711 255,975 294,769
Unregulated businesses..................................... 8,855 1,266 3,314
---------- ---------- ----------
Total operating revenues................................ 1,157,543 1,092,445 1,020,521
---------- ---------- ----------
Operating Expenses:
Cost of energy sold........................................ 531,952 449,426 409,717
Administrative and general................................. 153,709 135,727 124,591
Energy production costs.................................... 140,784 149,747 138,245
Depreciation and amortization.............................. 92,661 86,141 82,694
Transmission and distribution costs........................ 59,264 56,457 56,983
Taxes, other than income taxes............................. 34,084 37,992 36,803
Income taxes (note 7)...................................... 25,010 41,306 41,941
---------- ---------- ----------
Total operating expenses................................ 1,037,464 956,796 890,974
---------- ---------- ----------
Operating income........................................ 120,079 135,649 129,547
---------- ---------- ----------
Other Income and Deductions:
Other...................................................... 47,500 37,672 21,548
Income tax expense (note 7)............................... (17,298) (14,985) (8,384)
---------- ---------- ----------
Net other income and deductions......................... 30,202 22,687 13,164
---------- ---------- ----------
Income before interest charges.......................... 150,281 158,336 142,711
---------- ---------- ----------
Interest Charges:
Interest on long-term debt (note 3)........................ 65,899 50,929 46,670
Other interest charges..................................... 4,768 12,288 9,544
---------- ---------- ----------
Net interest charges.................................... 70,667 63,217 56,214
---------- ---------- ----------
Net Earnings from Continuing Operations...................... 79,614 95,119 86,497
Discontinued Operations, Net of Tax (note 13)................ - (12,437) (5,502)
Cumulative Effect of a Change in Accounting..................
Principle, Net of Tax (note 14)........................... 3,541 - -
---------- ---------- ----------
Net Earnings................................................. 83,155 82,682 80,995
Preferred Stock Dividend Requirements........................ 586 586 586
---------- ---------- ----------
Net Earnings Applicable to Common Stock...................... $ 82,569 $ 82,096 $ 80,409
========== ========== ==========
Net Earnings per Share of Common Stock (Basic) (note 6)...... $ 2.01 $ 1.97 $ 1.92
========== ========== ==========
Net Earnings per Share of Common Stock (Diluted) (note 6).... $ 2.01 $ 1.95 $ 1.91
========== ========== ==========
Dividends Paid per Share of Common Stock..................... $ 0.80 $ 0.77 $ 0.63
========== ========== ==========
The accompanying notes are an integral part of these financial statements.
F-3
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
As of December 31,
1999 1998
----------- -----------
(In thousands)
Utility Plant, at original cost except PVNGS: (notes 10, 11)
Electric plant in service................................................................. $1,976,009 $1,966,277
Gas plant in service...................................................................... 483,819 467,758
Common plant in service and plant held for future use..................................... 69,273 63,796
----------- -----------
2,529,101 2,497,831
Less accumulated depreciation and amortization............................................ 1,077,576 998,175
----------- -----------
1,451,525 1,499,656
Construction work in progress............................................................. 104,934 66,677
Nuclear fuel, net of accumulated amortization of $20,832 and $21,898...................... 25,923 27,426
----------- -----------
Net utility plant...................................................................... 1,582,382 1,593,759
----------- -----------
Other Property and Investments:
Other investments (notes 5, 12)........................................................... 483,008 518,959
Non-utility property, net of accumulated depreciation of $1,261 and $1,129................ 4,439 4,875
----------- -----------
Total other property and investments................................................... 487,447 523,834
----------- -----------
Current Assets:
Cash and cash equivalents................................................................. 120,399 61,280
Accounts receivables, net of allowance for uncollectible accounts of $12,504 and $836..... 147,746 130,809
Other receivables 68,911 59,745
Inventories............................................................................... 39,992 35,674
Regulatory assets (note 2)................................................................ 24,056 15,618
Other current assets...................................................................... 4,934 4,666
----------- -----------
Total current assets................................................................... 406,038 307,792
----------- -----------
Deferred charges:
Regulatory assets (note 2)................................................................ 195,898 186,383
Prepaid pension cost (note 8)............................................................. 16,126 16,714
Other deferred charges.................................................................... 35,377 40,121
----------- -----------
Total deferred charges................................................................. 247,401 243,218
----------- -----------
$2,723,268 $2,668,603
=========== ===========
The accompanying notes are an integral part of these financial statements.
F-4
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
CAPITALIZATION AND LIABILIITES
As of December 31,
--------------------------
1999 1998
------------ -----------
(In thousands)
Capitalization: (note 3)
Common stock equity:
Common stock outstanding--40,703 and 41,774 shares.......................... $ 203,517 $ 208,870
Additional paid-in capital.................................................. 453,393 465,386
Accumulated other comprehensive income, net of tax (note 3)................. 2,352 1,127
Retained earnings........................................................... 227,829 186,220
------------ -----------
Total common stock equity................................................ 887,091 861,603
Minority interest............................................................. 12,771 13,405
Cumulative preferred stock without mandatory redemption requirements.......... 12,800 12,800
Long-term debt, less current maturities (note 3).............................. 988,489 1,008,614
------------ -----------
Total capitalization....................................................... 1,901,151 1,896,422
------------ -----------
Current Liabilities:
Short-term debt............................................................... - 26,620
Accounts payable.............................................................. 150,645 113,975
Accrued interest and taxes.................................................... 34,237 34,289
Other current liabilities..................................................... 54,137 45,169
------------ -----------
Total current liabilities.................................................. 239,019 220,053
------------ -----------
Deferred Credits:
Accumulated deferred income taxes (note 7).................................... 153,335 129,990
Accumulated deferred investment tax credits (note 7).......................... 50,996 54,404
Regulatory liabilities (note 2) .............................................. 88,497 89,559
Regulatory liabilities related to accumulated deferred income tax (note 2) ... 14,935 14,287
Accrued postretirement benefits cost (note 8)................................. 8,945 4,675
Other deferred credits (note 12).............................................. 266,390 259,213
------------ -----------
Total deferred credits..................................................... 583,098 552,128
------------ -----------
Commitments and Contingencies (note 11)......................................... - -
------------ -----------
$2,723,268 $2,668,603
============ ===========
The accompanying notes are an integral part of these financial statements.
F-5
PUBLIC SERVICE COMPANY OF NEW MEXICO
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
---------------------------------
1999 1998 1997
---------- ---------- ---------
(In thousands)
Cash Flows From Operating Activities:
Net earnings............................................................. $ 83,155 $ 82,682 $ 80,995
Adjustments to reconcile net earnings to net cash flows..................
from operating activities:
Depreciation and amortization........................................ 103,891 98,154 94,924
Gain on cumulative effect of a change in
Accounting principle (note 14).................................... (5,862) - -
Other, net........................................................... 27,623 27,462 20,025
Changes in certain assets and liabilities:
Accounts receivables............................................... (16,937) 1,302 (14,038)
Other assets ...................................................... (20,189) 31,066 3,946
Accounts payable................................................... 36,670 (40,490) 23,808
Other liabilities.................................................. 6,147 10,812 3,462
---------- ---------- ---------
Net cash flows provided from operating activities............ 214,498 210,988 213,122
---------- ---------- ---------
Cash Flows From Investing Activities:
Utility plant additions.................................................. (95,298) (128,784) (128,371)
Return (purchase) of PVNGS lease obligation bonds........................ 16,903 (204,364) (23,882)
Other investing.......................................................... 22,509 (7,844) (29,814)
---------- ---------- ---------
Net cash flows used in investing activities.................. (55,886) (340,992) (182,067)
---------- ---------- ---------
Cash Flows From Financing Activities:
Borrowings (note 3)...................................................... 11,500 896,348 27,600
Repayments (note 3)...................................................... (58,200) (694,651) (28,870)
Exercise of employee stock options (note 9).............................. - (3,687) (1,285)
Common stock repurchase (note 3)......................................... (18,799) - -
Dividends paid........................................................... (33,359) (32,789) (26,864)
Other Financing.......................................................... (635) 7,868 (3,693)
---------- ---------- ---------
Net cash flows (used) generated by financing activities...... (99,493) 173,089 (33,112)
---------- ---------- ---------
Increase (Decrease) in Cash and Cash Equivalents........................... 59,119 43,085 (2,057)
Beginning of Year.......................................................... 61,280 18,195 20,252
---------- ---------- ---------
End of Year................................................................ $ 120,399 $ 61,280 $ 18,195
========== ========== =========
Supplemental cash flow disclosures:
Interest paid............................................................ $ 67,770 $ 50,109 $ 57,302
========== ========== =========
Income taxes paid, net of refunds........................................ $ 36,575 $ 49,048 $ 20,175
========== ========== =========
Acquired DOE pipeline in exchange for transportation services............ $ 3,100 - -
========== ========== =========
The accompanying notes are an integral part of these financial statements.
F-6
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
December 31,
1999 1998
----------- -----------
(In thousands)
Common Stock Equity: (note 3)
Common Stock, par value $5 per share.................................. $ 203,517 $ 208,870
Additional paid-in capital............................................ 453,393 465,386
Accumulated other comprehensive income, net of tax 2,352 1,127
Retained earnings..................................................... 227,829 186,220
----------- -----------
Total common stock equity......................................... 887,091 861,603
----------- -----------
Minority Interest......................................................... 12,771 13,405
----------- -----------
Cumulative Preferred Stock: (note 3)
Without mandatory redemption requirements:
1965 Series, 4.58% with a stated value of $100.00 and a
current redemption price of $102.00. Outstanding shares
at December 31, 1999 were 128,000................................ 12,800 12,800
----------- -----------
Long-Term Debt: (note 3)
Issue and Final Maturity
First Mortgage Bonds, Pollution Control Revenue Bonds:
5.7% due 2016................................................... 65,000 65,000
6.375% due 2022................................................... 46,000 46,000
----------- -----------
Total First Mortgage Bonds 111,000 111,000
----------- -----------
Senior Unsecured Notes, Pollution Control Revenue Bonds:
6.30% due 2016................................................. 77,045 77,045
5.75% due 2022................................................. 37,300 37,300
5.80% due 2022................................................. 100,000 100,000
6.375% due 2022................................................. 90,000 90,000
6.375% due 2023................................................. 36,000 36,000
6.40% due 2023................................................. 100,000 100,000
6.30% due 2026................................................. 23,000 23,000
6.60% due 2029................................................. 11,500 -
----------- -----------
Total Senior Unsecured Notes, Pollution Control Revenue Bonds.... 474,845 463,345
----------- -----------
Senior Unsecured Notes:
7.10% due 2005................................................ 268,420 300,000
7.50% due 2018................................................ 135,000 135,000
Other, including unamortized premium and (discounted), net........... (776) (731)
----------- -----------
Total long-term debt......................................... 988,489 1,008,614
----------- -----------
Total Capitalization...................................................... $1,901,151 $1,896,422
=========== ===========
The accompanying notes are an integral part of these financial statements.
F-7
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
December 31, 1999, 1998 and 1997
Summary of Significant Accounting Policies
Accounting Principles
The Company prepares its financial statements in accordance with the
uniform system of accounts prescribed by the Federal Energy Regulatory
Commission ("FERC") and the National Association of Regulatory Utility
Commissioners, and adopted by the New Mexico Public Regulation Commission
("PRC"), the successor of the New Mexico Public Utility Commission ("NMPUC"),
effective January 1, 1999.
The Company's accounting policies conform to the provisions of Statement
of Financial Accounting Standards No. 71, "Accounting for the Effects of Certain
Types of Regulation ("SFAS 71"). SFAS 71 requires a rate-regulated entity to
reflect the effects of regulatory decisions in its financial statements. In
accordance with SFAS 71, the Company has deferred certain costs and recorded
certain liabilities pursuant to the rate actions of the PRC, NMPUC and FERC.
These "regulatory assets" and "regulatory liabilities" are enumerated and
discussed in Note 2.
To the extent that the Company concludes that the recovery of a
regulatory asset is no longer probable due to regulatory treatment, the effects
of competition or other factors, the amount would be recorded as a charge to in
earnings as recovery is no longer probable. The Company has discontinued the
application of SFAS 71 as of December 31, 1999, for the generation portion of
its business effective with the passage of the Electric Utility Industry
Restructuring Act of 1999 ("Restructuring Act") in accordance with Financial
Accounting Standards No. 101, "Accounting for the Discontinuation of Application
of FASB Statement No. 71". The Company evaluated its regulatory assets under
Financial Accounting Standards No. 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets to be Disposed of" ("FAS 121") and
determined no impairment exists. The Company believes that it will recover costs
associated with stranded assets including asset closure costs through a
non-bypassable charge as permitted by the Restructuring Act. See Note 2 for
additional discussion.
Principles of Consolidation
The consolidated financial statements include the accounts of the Company
and subsidiaries in which it owns a majority voting interest. All significant
intercompany transactions and balances have been eliminated.
Financial Statement Preparation and Presentation
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual recorded amounts could differ from those estimated.
F-8
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
Summary of Significant Accounting Policies (Continued)
Utility Plant
Utility plant, with the exception of Palo Verde Nuclear Generating
Station ("PVNGS") Unit 3 and the Company's owned interests in PVNGS Units 1 and
2, is stated at original cost, which includes capitalized payroll-related costs
such as taxes, pension and other fringe benefits, administrative costs and an
allowance for funds used during construction. Pursuant to a rate stipulation
dated October 1993, the Company did not capitalize amounts relating to an
allowance for funds used during construction in 1999, 1998 or 1997. Utility
plant includes certain electric assets not subject to regulation.
It is Company policy to charge repairs and minor replacements of
property to maintenance expense and to charge major replacements to utility
plant. Gains or losses resulting from retirements or other dispositions of
operating property in the normal course of business are credited or charged to
the accumulated provision for depreciation.
Depreciation and Amortization
Provision for depreciation and amortization of utility plant is made at
annual straight-line rates approved by the PRC. The average rates used are as
follows:
1999 1998 1997
---- ---- ----
Electric plant ........................... 3.38% 3.32% 3.33%
Gas plant ................................ 3.37% 3.06% 3.23%
Common plant ............................. 7.73% 7.34% 7.60%
The provision for depreciation of certain equipment is charged to
clearing accounts and subsequently allocated to operating expenses or
construction projects based on the use of the equipment. Depreciation of
non-utility property is computed on the straight-line method. Amortization of
nuclear fuel is computed based on the units of production method.
Nuclear Decommissioning
The Company accounts for nuclear decommissioning costs on a
straight-line basis over the respective license period. Such amounts are based
on the future value of expenditures estimated to be required to decommission the
plant.
F-9
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
Summary of Significant Accounting Policies (Continued)
Recoverable Fuel Costs
The Company's fuel and purchased power costs for its firm requirements
wholesale customers that are above the levels included in base rates are
recoverable under a fuel and purchased power cost adjustment approved by the
FERC. Such costs are deferred until the period in which they are billed or
credited to customers. The Company's gas purchase costs that are above levels
included in base rates are recoverable under similar Purchased Gas Adjustment
Clause administered by the PRC. For gas, the excess or deficiency is accumulated
for refund or surcharge to customers on an annual basis. Future recovery of
these costs is subject to approval by the PRC.
Amortization of Debt Acquisition Costs
Discount, premium and expense related to the issuance of long-term debt
are amortized over the lives of the respective issues. In connection with the
retirement of long-term debt, such amounts associated with resources subject to
PRC regulation are amortized over the lives of the respective issues. Amounts
associated with the Company's firm-requirements wholesale customers and its
resources excluded from PRC retail rates are recognized immediately as expense
or income as they are incurred.
Stock Options
The Company continues to apply Accounting Principles Board ("APB")
Opinion No. 25, Accounting for Stock Issued to Employees, and related
interpretations in accounting for its plan. Accordingly, no compensation cost
has been recognized for this plan.
Income Taxes
The Company reports income tax expense in accordance with SFAS 109,
Accounting for Income Taxes. SFAS 109 requires that deferred income taxes for
temporary differences between financial and income tax reporting be recorded
using the liability method. Therefore, deferred income taxes are computed using
the statutory tax rates scheduled to be in effect when temporary differences
reverse. Current PRC jurisdictional rates include the tax effects of the
majority of these temporary differences (normalization). Recovery of reversing
temporary differences previously accounted for under the flow-through method is
also included in rates charged to customers. For regulated operations, any
changes in tax rates applied to accumulated deferred income taxes may not be
immediately recognized because of ratemaking and tax accounting provisions
required by the Internal Revenue Code. Items accorded flow-through treatment
under PRC orders, deferred income taxes and the future ratemaking effects of
such taxes, as well as corresponding regulatory assets and liabilities, are
recorded in the financial statements.
F-10
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
Summary of Significant Accounting Policies (Continued)
Asset Impairment
The Company regularly evaluates the carrying value of its regulatory and
tangible long-lived assets in relation to their future undiscounted cash flows
to assess recoverability in accordance with SFAS 121, Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of.
Impairment testing of power generation assets is performed quarterly in response
to changes in market conditions resulting from industry deregulation. Power
generation assets used to supply jurisdictional and wholesale markets are
evaluated on a group basis using future undiscounted cash flows based on current
open market price conditions. The Company also has generation assets that are
used for the sole purpose of reliability. These assets are tested as an
individual group. Power generation assets held under operating leases are not
currently evaluated for impairment (see note 4).
Financial Instruments
The Company periodically enters into energy trading contracts to take
advantage of market opportunities associated with the purchase and sale of
electricity. Such contracts are marked-to-market each period end. In addition,
the Company protected its decommissioning and retiree trust assets against
market price volatility by purchasing financial put and call options. These
instruments are also marked-to-market each period end. The Company also
periodically hedges natural gas purchases to limit commodity price volatility.
Unrealized gains and losses from natural gas-related swaps, futures and forward
contracts are deferred and recognized as the natural gas is sold and is
recovered through gas rates charged to customers (see Notes 5 and 14).
Accounting for Contracts Involved in Energy Trading and Risk Management
Activities
In December 1998, the Emerging Issues Task Force ("EITF") of the FASB
reached consensus on EITF Issue No. 98-10 which requires that energy trading
contracts should be marked to market (measured at fair value determined as of
the balance sheet date) with the gains and losses included in earnings.
Effective January 1, 1999, the Company adopted EITF Issue No. 98-10. The effect
of the initial application of the new standard is reported as a cumulative
effect of a change in accounting principle.
Change in Presentation
Certain prior year amounts have been reclassified to conform to the 1999
financial statement presentation.
F-11
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(1) Nature of Business and Segment Information
The Company is an investor-owned integrated utility engaged in the
generation, transmission, distribution and sale of electricity and the
transportation, distribution and sale of natural gas. In addition, the Company
provides energy and utility related services under its wholly-owned subsidiary,
Avistar, Inc. ("Avistar").
Under current law, the Company is not in any direct retail competition
with any other regulated electric and gas utility. The Restructuring Act in New
Mexico, which was enacted into law on April 8, 1999, opens the state's electric
power market to customer choice for certain customers beginning as early as 2001
with the balance of customers obtaining open access as early as 2002. The
Restructuring Act requires that assets and activities subject to the PRC
jurisdiction, primarily electric and gas distribution, and transmission assets
and activities (collectively, the "regulated business"), be separated from other
competitive business, primarily electric generation and service and certain
other energy services operations (collectively, "the competitive businesses").
Such separation is required to be accomplished through the creation of at least
two separate corporations. The Company has decided to accomplish the mandated
separation by the formation of a holding company and the transfer of the
regulated businesses to a newly-created, wholly owned subsidiary of such holding
company, subject to various regulatory and other approvals. Corporate separation
of the regulated business from the competitive businesses must be completed by
January 1, 2001, although such date may be extended by up to one year by the
PRC.
As it currently operates, the Company's principal business segments are
electric ("Electric") and gas ("Gas") operations. Electric consists of three
major business lines that include the Electric Service Business Unit
("Distribution"), Transmission Service Business Unit ("Transmission") and
Generation Business Unit ("Generation").
ELECTRIC OPERATIONS
The Company's electric operations serve four principal markets. Sales to
retail customers and sales to firm-requirements wholesale customers, sometimes
referred to collectively as "system" sales, comprise two of these markets. The
third market consists of other contracted sales to utilities for which the
Company commits to deliver a specified amount of capacity (measured in MW) or
energy (measured in MWh) over a given period of time. The fourth market consists
of economy energy sales made on an hourly basis at fluctuating, spot-market
rates. Sales to the third and fourth markets are sometimes referred to
collectively as "off-system" sales.
The Company provides retail electric service to a large area of north
central New Mexico, including the cities of Albuquerque and Santa Fe and certain
other areas of New Mexico. As of December 31, 1999, approximately 361,000 retail
electric customers were served by the Company, the largest of which accounted
for approximately 4.7% of the Company's total retail electric revenues for the
year ended December 31, 1999.
F-12
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(1) Nature of Business and Segment Information (Continued)
The Company has ownership interests in certain generating facilities
located in New Mexico, including the Four Corners Power Plant, a coal fired unit
("Four Corners"), and San Juan Generating Station, a coal fired unit ("SJGS").
In addition, the Company has ownership and leasehold interests in PVNGS located
in Arizona. These generation assets are used to supply retail and wholesale
customers. The Company also owns Reeves Station, a gas and oil fired unit
("Reeves") and Las Vegas Generating Station, a gas and oil fired unit ("Las
Vegas") that are used solely for reliability purposes or to generate electricity
for the wholesale market during peak demand periods in the Company's wholesale
power markets. As of December 31, 1999, the total net generation capacity of
facilities owned or leased by the Company was 1,506 MW. In addition to
generation capacity, the Company purchases power in the open market. The Company
is also interconnected with various utilities for economy interchanges and the
mutual assistance in emergencies. The Company has been actively trading in the
wholesale power market and has entered into and anticipates that it will
continue to enter into power purchase agreements to accommodate its trading
activity.
GAS OPERATIONS
The Company's gas operating division, Public Service Company of New
Mexico Gas Services, as division of the Company ("PNMGS"), distributes natural
gas to most of the major communities in New Mexico, including Albuquerque and
Santa Fe, serving approximately 426,000 customers as of December 31, 1999.
PNMGS' customer base includes both sales-service customers and
transportation-service customers. Sales-service customers purchase natural gas
and receive transportation and delivery services from PNMGS for which PNMGS
receives both cost-of-gas and cost-of-service revenues. Additionally, PNMGS
makes occasional gas sales to off-system customers. Transportation-service
customers, who procure gas independently of PNMGS and contract with PNMGS for
transportation and related services, provide PNMGS with cost-of-service revenues
only. Transportation services are provided to gas marketers, producers and end
users for delivery to locations throughout the PNMGS distribution systems, as
well as for delivery to interstate pipelines.
F-13
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(1) Nature of Business and Segment Information (Continued)
PNMGS obtains its supply of natural gas primarily from sources within
New Mexico pursuant to contracts with producers and marketers. These contracts
are generally sufficient to meet PNMGS peak-day demand. PNMGS serves certain
cities which depend on El Paso Natural Gas Company or Transwestern Pipeline
Company for transportation of gas supplies. Because these cities are not
directly connected to PNMGS transmission facilities, gas transported by these
companies is the sole supply source for those cities. Such transportation is
regulated by FERC. As a result of FERC Order 636, PNMGS' options for
transporting gas to such cities and other portions of its distribution system
have increased.
UNREGULATED
The Company's wholly-owned subsidiary, Avistar, was formed in August 1999
as a New Mexico corporation and is currently engaged in certain unregulated,
non-utility businesses, including energy and utility-related services previously
operated by the Company. The PRC authorized the Company to invest $50 million in
equity in Avistar and to enter into a reciprocal loan agreement for up to $30
million. The Company has currently invested $25 million in Avistar. In February
2000, Avistar invested $3 million in AMDAX.com, a start-up company which will
provide an on line auction service to bring together electricity buyers and
sellers in the deregulated electric power market. Avistar also operates and
manages the City of Santa Fe's water system.
RISKS AND UNCERTAINTIES
The Company's future results may be affected by changes in regional
economic conditions; the outcome of labor negotiations with unionized employees;
fluctuations in fuel, purchased power and gas prices; the actions of utility
regulatory commissions; environmental regulations and external factors such as
the weather. As a result of state and Federal regulatory reforms, the public
utility industry is undergoing a fundamental change. As this occurs, the
electric generation business is transforming into a competitive marketplace. The
Company's future results will be impacted by its ability to recover its stranded
costs, costs incurred previously in providing power generation to electric
service customers, and the costs of transition to an unregulated status. In
addition, as a result of deregulation, the Company may face competition from
companies with greater financial and other resources.
F-14
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(1) Nature of Business and Segment Information (Continued)
Summarized financial information by business segment for 1999, 1998 and
1997 is as follows:
Electric
-----------------------------------------------------
Distribution Transmission Generation Total Gas Unregulated Consolidated
------------ ------------ ---------- ----------- -------- ----------- ------------
(In thousands)
1999:
Operating revenues:
External customers.................. $ 525,348 $ 15,520 $ 371,109 $ 911,977 $ 236,711 $ 8,855 $1,157,543
Intersegment revenues............... - 29,801 318,872 348,673 - - 348,673
Depreciation and amortization.......... 23,564 8,373 40,949 72,886 19,775 92,661
Interest income........................ 13,731 4,569 20,681 38,981 9,093 6,095 54,169
Net interest charges................... 21,510 7,515 26,341 55,366 16,353 (1,052) 70,667
Income tax expense (benefit) from
Continuing operations................ 22,406 2,745 17,904 43,055 3,211 (3,958) 42,308
Operating income....................... 48,796 9,454 51,275 109,525 15,135 (4,581) 120,079
Cumulative effect of a change in
Accounting principle, net of tax..... - - 3,541 3,541 - - 3,541
Segment net income (loss).............. 34,939 4,615 41,644 81,198 4,171 (2,214) 83,155
Total assets........................... 593,485 207,132 1,394,283 2,194,900 502,838 25,530 2,723,268
Gross property additions............... 30,585 12,489 24,426 67,500 27,798 - 95,298
1998:
Operating revenues:
External customers.................. $ 539,972 $ 15,596 $ 279,636 $ 835,204 $ 255,975 $ 1,266 $1,092,445
Intersegment revenues............... - 29,091 362,722 391,813 - - 391,813
Depreciation and amortization.......... 23,396 8,527 38,292 70,215 15,863 63 86,141
Interest income........................ 9,200 4,286 15,001 28,487 6,130 424 35,041
Net interest charges................... 16,057 7,547 26,179 49,783 13,784 (350) 63,217
Income tax expense (benefit) from
Continuing operations................ 15,160 4,165 33,804 53,129 7,754 (4,592) 56,291
Operating income....................... 30,895 11,868 78,750 121,513 20,099 (5,963) 135,649
Discontinued operations, net of tax.... - - - - - (12,437) (12,437)
Segment net income (loss).............. 22,317 6,828 61,949 91,094 11,056 (19,468) 82,682
Total assets........................... 587,835 198,718 1,410,818 2,197,371 447,074 24,158 2,668,603
Gross property additions............... 50,399 9,156 30,969 90,524 38,260 - 128,784
F-15
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(1) Nature of Business and Segment Information (Continued)
Electric
-----------------------------------------------------
Distribution Transmission Generation Total Gas Unregulated Consolidated
------------ ------------ ---------- ----------- -------- ----------- ------------
(In thousands)
1997:
Operating revenues:
External customers.................. $522,835 - $ 199,603 $ 722,438 $294,769 $ 3,314 $1,020,521
Intersegment revenues............... - 370,019 370,019 - - 370,019
Depreciation and amortization.......... 21,754 - 46,335 68,089 14,587 18 82,694
Interest income........................ 6,715 - 12,714 19,429 4,313 34 23,776
Net interest charges................... 15,900 - 27,613 43,513 12,701 - 56,214
Income tax expense (benefit) from
Continuing operations................ 15,924 - 26,963 42,887 10,169 (2,731) 50,325
Operating income....................... 37,296 - 72,175 109,471 23,444 (3,368) 129,547
Discontinued operations, net of tax.... - - - - - (5,502) (5,502)
Segment net income (loss).............. 24,496 - 51,260 75,756 14,602 (9,363) 80,995
Total assets........................... 612,136 - 1,257,767 1,869,903 482,206 55,301 2,407,410
Gross property additions............... 45,302 - 51,661 96,963 31,408 - 128,371
The unregulated segment includes Avistar and certain corporate activities
which are not material.
The Transmission Service Business Unit was established in 1998. Prior to
1998, it was combined with the Bulk Power Business Unit. Prior periods
information for the Transmission Service Business Unit is not available.
On August 4, 1998, the Company adopted a plan to discontinue the natural
gas trading operations of its Energy Services Business Unit and completely
discontinued these operations on December 31, 1998 (see note 13).
F-16
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(2) Regulatory Assets and Liabilities
The Company is subject to the provisions of SFAS 71, with respect to
operations regulated by the PRC. Regulatory assets represent probable future
revenue to the Company associated with certain costs which will be recovered
from customers through the ratemaking process. Regulatory liabilities represent
probable future reductions in revenues associated with amounts that are to be
credited to customers through the ratemaking process. Regulatory assets and
liabilities reflected in the Consolidated Balance Sheets as of December 31,
relate to the following:
1999 1998
---- ----
(In thousands)
Assets:
Current:
PGAC ........................................... $ 19,310 $ 5,294
Gas Take-or-Pay Costs .......................... 4,746 10,324
-------- --------
Subtotal .................................... 24,056 15,618
-------- --------
Deferred:
Deferred Income Taxes .......................... 35,713 35,564
Loss on Reacquired Debt ........................ 8,133 8,499
Gas Imputed Revenues ........................... 7,290 6,726
Gas Reservation Fees ........................... 7,029 7,029
Deferred Customer Expense on Gas Assets Sale ... 6,468 5,260
Gas Retirees' Health Care Costs ................ 3,264 4,804
Proposed Transmission Line Costs ............... 2,432 2,660
Gas Rate Case Costs ............................ 1,571 1,571
Other .......................................... 331 471
-------- --------
Subtotal ................................... 72,731 72,584
-------- --------
Stranded and Transition Assets.................. 123,167 113,799
-------- --------
Total Assets................................. 219,454 202,001
-------- --------
Liabilities:
Deferred:
Deferred Income Taxes .......................... (31,880) (49,971)
Gas Regulatory Reserve ......................... (20,830) (21,308)
Customer Gain on Gas Assets Sale ............... (7,226) (7,226)
DOE Line Acquisition............................ (3,083) -
Gain on Reacquired Debt ........................ (708) (484)
Other........................................... (607) (774)
-------- --------
Subtotal..................................... (79,269) (70,763)
-------- --------
Stranded and Transition Liabilities............. (24,163) (24,083)
-------- --------
Total Liabilities............................ (103,432) (103,846)
-------- --------
Net Regulatory Assets ....................... $116,022 $ 98,155
======== ========
F-17
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(2) Regulatory Assets and Liabilities (Continued)
Substantially all of the Company's regulatory assets and regulatory
liabilities are reflected in rates charged to customers or have been addressed
in a regulatory proceeding.
In 1999, the State of New Mexico enacted the Restructuring Act that
provides guidelines to deregulated power generation activities in New Mexico and
opens the state's power markets to customer choice beginning as early as 2001.
The Restructuring Act recognizes that electric utilities should be permitted a
reasonable opportunity to recover an appropriate amount of the costs incurred
previously in providing electric service ("stranded costs"). Stranded costs
include plant decommissioning costs, regulatory assets, lease and lease-related
costs recognized under cost-of-service regulation. As of December 31, 1999, the
Company discontinued the use of the provisions of SFAS No. 71 for generation
activities due to the passage of the Restructuring Act. Utilities will be
allowed to recover no less than 50% of such costs through a non-bypassable
charge on all customer bills for five years after implementation of customer
choice. The PRC could authorize a utility to recover up to 100% of its stranded
costs if the PRC finds that recovery of more than 50%: (i) is in the public
interest; (ii) is necessary to maintain the financial integrity of the public
utility; (iii) is necessary to continue adequate and reliable service; and (iv)
will not cause an increase in rates to residential or small business customers
during the transition period. The Restructuring Act also allows for the recovery
of decommissioning costs by means of a separate wires charge. The Company
expects to recover its regulatory assets associated with the deregulated
business through its stranded costs recovery. As a result, a regulatory asset
has been established to reflect the costs associated with discontinuation of
SFAS 71 accounting and adoption of SFAS 101. The Company's estimate of its
stranded costs, including nuclear and fossil fuel decommissioning costs, ranges
from $530 million to $730 million which includes other operating costs in excess
of its related regulatory assets. The Company believes that it will recover
these costs as permitted under the restructuring act. Final determination and
quantification of stranded cost recovery has not been made by the PRC. Such
determination will have an impact on the recoverability of the related assets.
Pursuant to the Restructuring Act, utilities will also be allowed to
recover in full any prudent and reasonable costs incurred in implementing full
open access ("transition costs"). The transition costs will be recovered through
2007 by means of a separate wires charge. The Company estimates that these costs
as being in excess of $50 million. Transition costs include, but are not limited
to, professional fees, financing costs including underwriting fees, consents
relating to the transfer to assets, management information system changes
including billing system changes and public and customer communications.
Recoverable transition costs will be capitalized and amortized over the recovery
period to match related revenues. Costs not recoverable will be expensed when
incurred unless otherwise capitalizable under the accounting rules.
F-18
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(2) Regulatory Assets and Liabilities (Continued)
Regulatory assets and liabilities reflected in the Consolidated Balance
Sheets as of December 31, 1999, related to stranded or transitions costs are as
follows:
1999 1998
--------- ---------
(In thousands)
Assets
Transition Costs................................ $ 4,293 $ -
Mine Reclamation Costs.......................... 78,856 75,101
Deferred Income Taxes........................... 37,725 36,089
Loss on Reacquired Debt......................... 2,293 2,609
--------- ---------
Subtotal................................... 123,167 113,799
--------- ---------
Liabilities
Deferred Income Taxes........................... (14,935) (14,287)
PVNGS Prudence Audit............................ (5,809) (6,185)
Settlement Due Customers........................ (3,384) (3,564)
Gain on Reacquired Debt......................... (35) (47)
--------- ---------
Subtotal................................... (24,163) (24,083)
--------- ---------
Net Stranded Cost and Transition Cost...... $ 99,004 $ 89,716
========= =========
Based on a current evaluation of the various factors and conditions that
are expected to impact future cost recovery, the Company believes that its net
regulatory assets are probable of future recovery.
F-19
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(3) Capitalization
Changes in common stock, additional paid-in capital, retained earnings and
comprehensive income are as follows:
Common Stock
-----------------------------
Additional
Number Aggregate Paid-In Retained Comprehensive
Of Shares Par Value Capital Earnings Income
--------- --------- ---------- -------- -------------
(Dollars in thousands)
Balance at December 31, 1997................. 41,774,083 $ 208,870 $469,073 $ 129,188 $ 486
Exercise of stock options.................... - - (3,687) - -
Net earnings................................. - - - 82,682 -
Dividends:
Cumulative preferred stock................ - - - (586) -
Common Stock.............................. - - - (25,064) -
Other Comprehensive Income, net of tax:
Unrealized gain (loss) on securities:
Unrealized holding gains arising
During the period...................... - - - - 1,519
Less reclassification adjustment for
Gains included in net income............ - - - - (673)
Minimum pension liability adjustment....... - - - - (205)
----------- ----------- ---------- ----------- ---------
Balance at December 31, 1998................. 41,774,083 208,870 465,386 186,220 1,127
Stock Repurchase............................. (1,070,700) (5,353) (11,993) - -
Net earnings................................. - - - 83,155 -
Dividends:
Cumulative preferred stock................ - - - (586) -
Common Stock.............................. - - - (40,960) -
Other Comprehensive Income, net of tax:
Unrealized gain (loss) on securities:
Unrealized holding gains arising
During the period...................... - - - - 4,120
Less reclassification adjustment for
Gains included in net income............ - - - - (4,282)
Minimum pension liability adjustment....... 1,387
----------- ----------- ---------- ----------- ---------
Balance at December 31, 1999................. 40,703,383 $ 203,517 $ 453,393 $ 227,829 $ 2,352
=========== =========== ========== =========== =========
F-20
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(3) Capitalization (Continued)
Comprehensive Income
The Company's investments held in rabbi trust for nuclear decommissioning
and certain retirement benefits are classified as available-for-sale, and
accordingly unrealized holding gains and losses are recognized as a component of
comprehensive income. Realized gains and losses are included in earnings. Net
losses related to the Company's pension plans, not yet recognized as net
periodic pension costs (or additional minimum liability) are reported as a
component of comprehensive income. Changes in the liability are adjusted as
necessary. All components of comprehensive income are recorded, net of any tax
benefit or expense. A deferred asset or liability is established for the
resulting temporary difference.
Common Stock
The number of authorized shares of common stock with par value of $5 per
share is 80 million shares. The declaration of common dividends is dependent on
a number of factors, including the extent to which cash flows will support
dividends, the availability of retained earnings, the financial circumstances
and performance of the Company, the PRC's decisions on the Company's various
regulatory cases currently pending. The effect of deregulating generation
markets and market and economic conditions generally. In addition, the ability
to recover stranded costs in deregulation, future growth plans and the related
capital requirements and standard business considerations will also affect the
Company's ability to pay dividends.
In March 1999, the Company's Board of Directors approved a plan to
repurchase up to 1,587,000 shares of the Company's outstanding common stock with
maximum purchase price of $19.00 per share. The repurchase program was created
to facilitate the Company's stock option program. In December 1999, the
Company's Board of Directors authorized the Company to repurchase up to an
additional $20.0 million of the Company's common stock. As of December 31, 1999,
the Company had repurchased 1,070,700 shares of its previously outstanding
common stock at a cost of $18.8 million. From January 2, 2000 through February
29, 2000, the Company repurchased an additional 963,284 shares of its previously
outstanding common stock at a cost of $15.7 million. The Company may from
time-to-time repurchase additional common stock for various corporate purposes.
On September 16, 1996, the Company implemented a dividend reinvestment
and stock purchase plan for investors, including customers and employees. The
plan, called PNM Direct, also includes safekeeping services and automatic
investment features. The Company's stock is purchased in the open market to meet
plan requirements.
Cumulative Preferred Stock
The number of authorized shares of cumulative preferred stock is 10
million shares. The Company has 128,000 shares, 1965 Series, 4.58%, stated value
of $100 per share, of cumulative preferred stock outstanding. The 1965 Series
does not have a mandatory redemption requirement but may be redeemable at 102%
of the par value with accrued dividends. The holders of the 1965 Series are
entitled to payment before holders of common stock in the event of any
liquidation or dissolution or distribution of assets of the Company. In
addition, the 1965 Series is not entitled to a sinking fund and cannot be
converted into any other class of stock of the Company. The Company's restated
articles of incorporation limit the amount of preferred stock which may be
issued. The earnings test in the Company's restated articles of incorporation
currently allows for the issuance of additional preferred stock.
F-21
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(3) Capitalization (Continued)
Long-Term Debt
The Company has no long-term debt that matures from 2000 through 2004.
On March 11, 1998, the Company modified its 1947 Indenture of Mortgage
and Deed of Trust; no future bonds can be issued under the mortgage. The first
mortgage bonds continue to serve as collateral for the tax-exempt pollution
control revenue bonds ("PCBs") in the outstanding principal amount of $111
million.
In March 1998, the Company replaced the first mortgage bonds
collateralizing $463 million of PCBs with senior unsecured notes ("SUNs") which
were issued under a new senior unsecured note indenture. Also, in March 1998,
the Company retired $140 million principal amount of first mortgage bonds. While
first mortgage bonds continue to serve as collateral for PCBs in the outstanding
principal amount of $111 million, the lien of the mortgage was substantially
reduced to cover only the Company's ownership interest in PVNGS. With the
exception of the $111 million of PCBs secured by first mortgage bonds, the SUNs
are and will be the senior debt of the Company.
In August 1998, the Company issued and sold $435 million of SUNs in two
series, the 7.10% Series A due August 1, 2005, in the principal amount of $300
million, and the 7.50% Series B due August 1, 2018, in the principal amount of
$135 million. These SUNs were issued under an indenture similar to the indenture
under which the SUNs were issued in March 1998, and it is expected that future
long-term debt financings will be similarly issued.
In 1999, the Company retired $31.6 million of its 7.1% senior unsecured
notes through open market purchases, utilizing the funds from operations and the
funds from temporary investments. On October 28, 1999, tax-exempt pollution
control revenue bonds of $11.5 million with an interest rate of 6.60% were
issued to partially reimburse the Company for expenditures associated with its
share of a recently completed upgrade of the emission control system at SJGS.
The gain recognized was immaterial. In January 2000, the Company reacquired
$35.0 million of its 7.5% senior unsecured notes through open market purchases.
F-22
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(3) Capitalization (Continued)
Revolving Credit Facility and Other Credit Facilities
At December 31, 1999, the Company had a $300 million unsecured revolving
credit facility (the "Facility") with an expiration date of March 31, 2003. The
Company must pay commitment fees of .1875% per year on the total amount of the
Facility. The Company also had an $80 million credit facility, which expired on
May 20, 2001, and was collateralized by the Company's electric and gas customer
accounts receivable and certain amounts being recovered from gas customers
relating to certain gas contract settlements. In addition, the Company had $25
million in local lines of credit. On February 15, 2000, the Company reduced the
borrowing capacity under its $300 million revolving credit facility to $150
million and terminated its $80 million securitization facility.
(4) Lease Commitments
The Company leases interests in Units 1 and 2 of PVNGS, certain
transmission facilities, office buildings and other equipment under operating
leases. The lease expense for PVNGS is $66.3 million per year over base lease
terms expiring in 2015 and 2016. Covenants in the Company's PVNGS Units 1 and 2
lease agreements limit the Company's ability, without consent of the owner
participants and bondholders in the lease transactions, (i) to enter into any
merger or consolidation, or (ii) except in connection with normal dividend
policy, to convey, transfer, lease or dividend more than 5% of its assets in any
single transaction or series of related transactions.
Future minimum operating lease payments (in thousands) at December 31, 1999
are:
2000 ................................................ $ 79,675
2001 ................................................ 78,726
2002 ................................................ 78,613
2003 ................................................ 78,610
2004 ................................................ 78,610
Later years ......................................... 799,197
----------
Total minimum lease payments ...................... $1,193,431
==========
Operating lease expense, inclusive of PVNGS leases, was approximately
$81.1 million in 1999, $82.6 million in 1998 and $80.8 million in 1997.
Aggregate minimum payments to be received in future periods under noncancelable
subleases are approximately $4.6 million.
F-23
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(5) Financial Instruments
The Company uses derivative financial instruments in limited instances to
manage risk as it relates to changes in natural gas and electric prices and
adverse market changes for investments held by the Company's various trusts. The
Company also uses, on a limited basis, certain derivative instruments for bulk
power electricity trading purposes in order to take advantage of favorable price
movements and market timing activities in the wholesale power markets.
The estimated fair value of the Company's financial instruments
(including current maturities) at December 31, is as follows:
1999 1998
------------------- -----------------------
Carrying Fair Carrying Fair
Amount Value Amount Value
-------- -------- ---------- ----------
(In thousands)
Long-Term Debt ............................... $(988,489) $(932,687) $(1,008,614) $(1,042,557)
Decommissioning Trust Debt.................... - - 26,620 26,620
Investment in PVNGS Lessors' Notes............ 424,605 455,888 443,748 459,167
Derivatives .................................. - (25,921) - 11,307
Decommissioning Trust......................... 51,752 51,770 59,803 64,509
Fossil-Fueled Plant Decommissioning Trust..... 4,591 4,591 7,676 7,676
Rabbi Trust................................... 16,901 16,931 9,804 17,012
Fair value is based on market quotes provided by the Company's
investment bankers and trust advisors.
The carrying amounts reflected on the consolidated balance sheets
approximate fair value for cash, temporary investments, and receivables and
payables due to the short period of maturity.
The Company is exposed to credit losses in the event of non-performance
or non-payment by counterparties. The Company uses a credit management process
to assess and monitor the financial conditions of counterparties.
Natural Gas Contracts
Pursuant to an order issued by the NMPUC, predecessor to the PRC, the
Company has previously entered into swaps to hedge certain portions of natural
gas supply contracts in order to protect the Company's natural gas customers
from the risk of adverse price fluctuations in the natural gas market. The
financial impact of all hedge gains and losses from swaps flowed through the
Company's purchased gas adjustment clause and are fully recoverable by the
Company. As a result, earnings were not affected by gains or losses generated by
these instruments. The Company hedged 40% of its natural gas deliveries during
the 1998-1999 heating season. Less than 15.5% of the 1998-1999 heating season
portfolio was hedged using financial hedging contracts. The Company has hedged a
portion of its 1999-2000 heating season gas supply portfolio through the use of
both physical and financial hedging tools. Less than 9.1% of the Company's
1999-2000 heating season portfolio is hedged using financial hedging contracts.
As of December 31, 1999, the Company had unrecognized mark-to-market losses of
$1.1 million associated with its gas-related financial hedging activities.
F-24
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(5) Financial Instruments (Continued)
Electricity Trading Contracts
To take advantage of market opportunities associated with the purchase
and sale of electricity, the Company's wholesale power operation periodically
enters into derivative financial instrument contracts. In addition, the Company
enters into forward physical contracts and physical options. The Company
accounts for these financial instruments as trading activities under the
accounting guidelines set forth under The Emerging Issues Task Force ("EITF")
Issue No. 98-10. As a result, all open contracts are marked to market at the end
of each period. The physical contracts are subsequently recognized as revenues
or purchased power when the actual physical delivery occurs. The effect of the
initial application of the new standard is reported as a cumulative effect of a
change in accounting principle. Accordingly, the Company recorded additional
earnings, net of taxes, of approximately $3.5 million, or $0.08 per common
share, to recognize the gain on net open physical electricity purchase and sales
commitments considered to be trading activities.
Through December 31, 1999, the Company's wholesale electric trading
operations settled trading contracts for the sale of electricity that generated
$43.9 million of electric revenues by delivering 1.2 million KWh. The Company
purchased $46.2 million or 1.4 million KWh of electricity to support these
contractual sale and other open market sales opportunities.
As of December 31, 1999, the Company had open trading contract
positions to buy $29.1 million and to sell $32.3 million of electricity. At
December 31, 1999, the Company had a gross mark-to-market gain (asset position)
on these trading contracts of $6.9 million and gross mark-to-market loss
(liability position) of $6.8 million, with net mark-to-market gain (asset
position) of $0.1 million. The mark-to-market valuation is recognized in
earnings each period.
Corporate Hedge
The Company has about $62 million invested in domestic stocks in
various trusts for nuclear decommissioning, executive retirement and retiree
medical benefits. At the end of March 1999, the Company began using financial
derivatives based on the Standard & Poor's ("S&P") 500 Index to limit potential
loss on these investments due to adverse market fluctuations. The options are
structured as a collar, protecting the portfolio against losses beyond a certain
amount and balancing the cost of that downside protection by foregoing gains
above a certain level. If the S&P 500 Index is within the specified range when
the option contract expires, the Company will not be obligated to pay, nor will
the Company have the right to receive cash. The Company accounts for the market
value changes of these options under mark-to-market accounting on a quarterly
basis. At December 31, 1999, the Company recorded an unrealized year-to-date
loss of $2.6 million (pre-tax) on the market value of these options, although
the S&P 500 Index is still within the specified range of the collar.
F-25
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(6) Earnings Per Share
In accordance with SFAS No. 128, Earnings per Share, dual presentation
of basic and diluted earnings per share has been presented in the Consolidated
Statements of Earnings. The following reconciliation illustrates the impact on
the share amounts of potential common shares and the earnings per share amounts:
1999 1998 1997
--------- --------- ---------
Basic:
Net Earnings from Continuing Operations.............................. $ 79,614 $ 95,119 $ 86,497
Discontinued Operations, net of tax (note 13): - (12,437) (5,502)
Cumulative Effect of a Change in Accounting
Principle, net of tax (note 14)................................... 3,541 - -
--------- --------- ---------
Net Earnings......................................................... 83,155 82,682 80,995
Preferred Stock Dividend Requirements................................ 586 586 586
--------- --------- ---------
Net Earnings Applicable to Common Stock.............................. $ 82,569 $ 82,096 $ 80,409
========= ========= =========
Average Number of Common Shares Outstanding.......................... 41,038 41,774 41,774
========= ========= =========
Net Earnings (Loss) per Share of Common Stock:
Earnings from continuing operations................................ $ 1.93 $ 2.27 $ 2.05
Discontinued operations (note 13).................................. - (0.30) (0.13)
Cumulative effect of a change in accounting principle (note 14).... 0.08 - -
--------- --------- ---------
Net Earnings per Share of Common Stock (Basic)....................... $ 2.01 $ 1.97 $ 1.92
========= ========= =========
Diluted:
Net Earnings from Continuing Operations.............................. $ 79,614 $ 95,119 $ 86,497
Discontinued Operations, net of tax (note 13)........................ - (12,437) (5,502)
Cumulative Effect of a Change in Accounting
Principle, net of tax (note 14)................................... 3,541 - -
--------- --------- ---------
Net Earnings......................................................... 83,155 82,682 80,995
Preferred Stock Dividend Requirements................................ 586 586 586
--------- --------- ---------
Net Earnings Applicable to Common Stock.............................. $ 82,569 $ 82,096 $ 80,409
========= ========= =========
Average Number of Common Shares Outstanding.......................... 41,038 41,774 41,774
Diluted effect of common stock equivalents (a)....................... 65 298 217
--------- --------- ---------
Average common and common equivalent shares
Outstanding........................................................ 41,103 42,072 41,991
========= ========= =========
Net Earnings (Loss) per Share of Common Stock:
Earnings from continuing operations................................ $ 1.93 $ 2.25 $ 2.05
Discontinued operations............................................ - (0.30) (0.13)
Cumulative effect of a change in accounting principle.............. 0.08 - -
--------- --------- ---------
Net Earnings per Share of Common Stock (Basic)....................... $ 2.01 $ 1.95 $ 1.91
========= ========= =========
(a) Excludes the effect of average anti-dilutive common stock equivalents
related to out of-the-money options of 66,143; 23,794; and 36,310 for the years
ended 1999, 1998 and 1997, respectively.
F-26
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(7) Income Taxes
Income taxes before discontinued operations and cumulative effect of a
change in accounting principle consist of the following components:
1999 1998 1997
---- ---- ----
(In thousands)
Current Federal income tax .................... $23,511 $32,785 $35,875
Current state income tax ...................... 8,502 11,451 10,502
Deferred Federal income tax ................... 13,494 15,797 8,781
Deferred state income tax ..................... 210 (324) (397)
Amortization of accumulated investment
tax credits ................................. (3,409) (3,418) (4,436)
------- ------- -------
Total income taxes ......................... $42,308 $56,291 $50,325
======= ======= =======
Charged to operating expenses ................. $25,010 $41,306 $41,941
Charged to other income and deductions ....... 17,298 14,985 8,384
------- ------- -------
Total income taxes........................ $42,308 $56,291 $50,325
======= ======= =======
The Company's provision for income taxes before discontinued operations
and cumulative effect of a change in accounting principle differed from the
Federal income tax computed at the statutory rate for each of the years shown.
The differences are attributable to the following factors:
1999 1998 1997
---- ---- ----
(In thousands)
Federal income tax at statutory rates .......... $42,673 $52,993 $47,888
Investment tax credits ........................ (3,409) (3,418) (4,436)
Depreciation of flow-through items ............ 605 531 519
Gains on the sale and leaseback of PVNGS
Units 1 and 2 .............................. (527) (527) (527)
Dividends received deduction (1,301) - -
Annual reversal of deferred income taxes
accrued at prior tax rates (2,320) (1,905) (1,082)
State income tax .............................. 5,541 7,074 6,381
Other ......................................... 1,046 1,543 1,582
------- ------- -------
Total income taxes ......................... $42,308 $56,291 $50,325
======= ======= =======
Effective tax rate 34.70% 37.18% 36.78%
F-27
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(7) Income Taxes (Continued)
Deferred income taxes result from certain temporary differences between
the recognition of income and expense for tax and financial reporting purposes,
as described in the Summary of Significant Accounting Policies. The major
sources of these differences for which deferred taxes have been provided and the
tax effects of each are as follows:
1999 1998 1997
---- ---- ----
(In thousands)
Deferred fuel costs .......................... $ 3,176 $(11,097) $(9,133)
Depreciation and cost recovery ............... 5,111 7,526 6,390
Contributions in aid of construction ......... (1,709) (2,826) (3,185)
Alternative minimum tax in excess of
regular tax ................................ 15,634 21,144 12,482
PVNGS decommissioning costs .................. (793) (618) (1,512)
Contribution to 401(h) plan .................. (1,185) (763) 3,181
PVNGS spent fuel disposal costs .............. (5,202) - -
Other ........................................ (1,328) 2,107 161
------- -------- -------
Net deferred taxes provided ............... $13,704 $ 15,473 $ 8,384
======= ======== =======
The components of the net accumulated deferred income tax liability
were:
1999 1998
---- ----
(In thousands)
Deferred Tax Assets:
Alternative minimum tax credit carryforward .... $ 18,420 $ 34,055
Nuclear decommissioning costs.................... 22,073 20,062
Regulatory liabilities related to income taxes .. 44,547 47,615
Other ........................................... 52,199 45,480
-------- --------
Total deferred tax assets .................... $137,239 $147,212
======== ========
Deferred Tax Liabilities:
Depreciation .................................... $184,687 $184,462
Investment tax credit ........................... 50,996 54,404
Fuel costs ...................................... 15,984 12,808
Regulatory assets related to income taxes........ 71,170 69,298
Other ........................................... 33,668 24,921
-------- --------
Total deferred tax liabilities ............... 356,505 345,893
-------- --------
Accumulated deferred income taxes, net ............. $219,266 $198,681
======== ========
F-28
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(7) Income Taxes (Continued)
The following table reconciles the change in the net accumulated
deferred income tax liability to the deferred income tax expense included in the
consolidated statement of earnings for the period:
Net change in deferred income tax liability per above table......... $20,585
Change in tax effects of income tax related regulatory
assets and liabilities ........................................... (4,940)
Tax effect of excess pension liability.............................. (910)
Tax effect of mark-to-market on investments available for sale...... (2,119)
Deferred tax expense relating to cumulative effect of a change
in accounting principle.......................................... (2,321)
-------
Deferred income tax expense from continuing operations
for the period................................................... $10,295
=======
The Company has no net operating loss carryforwards as of December 31,
1999.
The Company defers investment tax credits related to rate regulated
assets and amortizes them over the estimated useful lives of those assets. The
Company anticipates that this practice will continue after the generation assets
are no longer rate regulated upon full implementation of the Restructuring Act
in 2002.
(8) Pension and Other Postretirement Benefits
Pension Plan
The Company and its subsidiaries have a pension plan covering
substantially all of their union and non-union employees, including officers.
The plan is non-contributory and provides for benefits to be paid to eligible
employees at retirement based primarily upon years of service with the Company
and the average of their highest annual base salary for three consecutive years.
The Company's policy is to fund actuarially-determined contributions.
Contributions to the plan reflect benefits attributed to employees' years of
service to date and also for services expected to be provided in the future.
Plan assets primarily consist of common stock, fixed income securities, cash
equivalents and real estate.
In December 1996, the Board of Directors approved changes to the
Company's non-contributory defined benefit plan ("Retirement Plan") and
implementation of a 401(k) defined contribution plan effective January 1, 1998.
Salaries used in Retirement Plan benefit calculations were frozen as of December
31, 1997. Additional credited service can be accrued under the Retirement Plan
up to a limit determined by age and years of service. The Company contributions
to the 401(k) plan consist of a 3 percent non-matching contribution, and a 75
percent match on the first 6 percent contributed by the employee on a before-tax
basis. The Company contributed $8.4 million in the years ended December 31, 1999
and 1998.
F-29
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(8) Pension and Other Postretirement Benefits (Continued)
The following sets forth the pension plan's funded status, components
of pension costs and amounts (in thousands) at December 31:
Pension Benefits
--------------------
1999 1998
---------- ---------
Change in Benefit Obligation:
Benefit obligation at beginning of year............. $ 330,048 297,679
Service cost........................................ 7,407 6,660
Interest cost....................................... 21,777 20,101
Actuarial loss...................................... (12,797) 19,380
Benefits paid....................................... (15,374) (13,772)
---------- ---------
Benefit obligation at end of period............. 331,061 330,048
---------- ---------
Change in Plan Assets:
Fair value of plan assets at beginning of year...... 330,556 330,550
Actual return on plan assets........................ 46,458 13,593
Employer contribution............................... - 185
Benefits paid....................................... (15,374) (13,772)
---------- ---------
Fair value of plan assets at end of year........ 361,640 330,556
---------- ---------
Funded Status....................................... 30,579 508
Unamortized transition assets....................... (2,322) (3,486)
Unrecognized net actuarial loss..................... (12,209) 19,580
Unrecognized prior service cost..................... 78 112
---------- ---------
Prepaid pension cost............................ $ 16,126 $ 16,714
========== =========
Weighted - Average Assumptions as of December 31,
Discount rate....................................... 7.50% 6.75%
Expected return on plan assets...................... 8.50% 8.50%
Rate of compensation increase....................... N/A N/A
Pension Benefits
-----------------------------
1999 1998 1997
--------- -------- ---------
Components of Net Periodic Benefit Cost:
Service cost................................ $ 7,407 $ 6,660 $ 6,535
Interest cost............................... 21,777 20,101 19,592
Expected return on plan assets.............. (27,466) (26,755) (23,426)
Amortization of prior service cost.......... (1,130) (1,130) (1,130)
--------- --------- ---------
Net periodic pension expense (income)... $ 588 $ (1,124) $ 1,571
========= ========= =========
F-30
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(8) Pension and Other Postretirement Benefits (Continued)
Other Postretirement Benefits
The Company provides medical and dental benefits to eligible retirees.
Currently, retirees are offered the same benefits as active employees after
reflecting Medicare coordination. The following sets forth the plan's funded
status, components of net periodic benefit cost (in thousands) at December 31:
Other Benefits
-------------------
1999 1998
-------- --------
Change in Benefit Obligation:
Benefit obligation at beginning of year............. $ 74,539 $ 59,084
Service cost........................................ 1,402 1,292
Interest cost....................................... 4,782 4,501
Actuarial loss (gain)............................... (6,958) 9,662
--------- ----------
Benefit obligation at end of period............. 73,765 74,539
--------- ----------
Change in Plan Assets:
Fair value of plan assets at beginning of year...... 37,602 33,158
Actual return on plan assets........................ 5,269 4,444
Employer contribution............................... 597 -
Benefits paid....................................... (1,643) -
--------- ----------
Fair value of plan assets at end of year........ $ 41,825 $ 37,602
--------- ----------
Funded Status....................................... $(31,940) $(36,937)
Unamortized transition assets....................... (622) 6,826
Unrecognized prior service cost..................... 23,617 25,436
Accrued postretirement benefits cost........... $ (8,945) $ (4,675)
Weighted - Average Assumptions as of December 31,
Discount rate....................................... 7.50% 6.75%
Expected return on plan assets...................... 8.75% 8.75%
Rate of compensation increase....................... N/A N/A
Pension Benefits
----------------------------
1999 1998 1997
-------- -------- --------
Components of Net Periodic Benefit Cost:
Service cost................................ $ 1,402 $ 1,292 $ 1,300
Interest cost............................... 4,782 4,501 4,452
Expected return on plan assets.............. (3,135) (2,943) (1,884)
Amortization of prior service cost.......... 1,817 1,817 1,817)
--------- -------- --------
Net periodic pension expense ........... $ 4,866 $ 4,667 $ 5,685
========= ======== ========
F-31
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(8) Pension and Other Postretirement Benefits (Continued)
The effect of a 1% increase in the health care trend rate assumption
would increase the accumulated postretirement benefit obligation as of December
31, 1999, by approximately $12.1 million and the aggregate service and interest
cost components of net periodic postretirement benefit cost for 1999 by
approximately $1.4 million. The health care cost trend rate is expected to
decrease to 5.0% by 2010 and to remain at that level thereafter.
Executive Retirement Program
The Company has an executive retirement program for a group of management
employees. The program was intended to attract, motivate and retain key
management employees. The Company's projected benefit obligation for this
program, as of December 31, 1999, was $18.1 million, of which the accumulated
and vested benefit obligation was $19.5 million. As of December 31, 1999, the
Company has recognized an additional liability of $3.6 million for the amount of
unfunded accumulated benefits in excess of accrued pension costs. The net
periodic cost for 1999, 1998 and 1997 was $2.3 million, $2.3 million and $2.2
million, respectively. In 1989, the Company established an irrevocable grantor
trust in connection with the executive retirement program. Under the terms of
the trust, the Company may, but is not obligated to, provide funds to the trust,
which was established with an independent trustee, to aid it in meeting its
obligations under such program. Marketable securities in the amount of
approximately $12.1 million (fair market value of $16.9 million) are presently
in trust. No additional funds have been provided to the trust since 1989.
(9) Stock Option Plans
The Company's Performance Stock Plan ("PSP") is a non-qualified stock
option plan, covering a group of management employees. Options to purchase
shares of the Company's common stock are granted at the fair market value of the
shares on the date of the grant. Options granted through December 31, 1995 vest
on June 30, 1996 and have an exercise term of up to 10 years. All subsequent
awards granted after December 31, 1995, vest three years from the grant date of
the awards. Options granted or approved on or after February 9, 1998, can also
vest upon retirement. The maximum number of options authorized are five million
shares through December 31, 2000.
In addition, the Company has a Director Retainer Plan ("DRP") which
provides for payment of the Directors' annual retainer in the form of cash,
restricted stock or options to purchase shares of the Company's common stock.
The number of options granted in 1999 under the DRP was 8,000 shares with an
exercise price of $9.69. No options were exercised under the DRP during 1999.
The maximum number of options authorized are 100,000 shares through April 30,
2002. The number of options outstanding as of December 31, 1999, was 29,000.
The fair value of each option grant is determined on the date of grant
using the Black-Scholes option-pricing model with the following average
assumptions used for grants in 1997, 1998 and 1999, respectively: dividend yield
of 3.0%, 3.75% and 4.9%; expected volatility of 20%, 26.78% and 30.29%,
risk-free interest rates of 5.69%, 4.65% and 6.43%; and expected lives of four
years.
F-32
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(9) Stock Option Plans (Continued)
A summary of the status of the Company's stock option plans at December
31, and changes during the years then ended is presented below. Prior periods
have been restated for comparability purposes.
1999 1998 1997
---------------------- -------------------- ----------------------
Weighted Weighted Weighted
Average Average Average
Exercise Exercise Exercise
Fixed Options Shares Price Shares Price Shares Price
- ---------------------------------------- --------- -------- --------- --------- -------- --------
Outstanding at beginning of year........ 996,175 $18.819 1,539,214 $17.704 1,619,406 $15.905
Granted................................. 608,708 $17.397 10,000 $12.750 312,707 $23.033
Exercised............................... - N/A 473,063 $14.663 379,833 $14.453
Forfeited............................... 19,949 $18.649 79,976 $21.194 13,066 $19.450
---------- ---------- -----------
Outstanding at end of year.............. 1,584,934 996,175 $18.819 1,539,214 $17.704
========== ========== ===========
Options exercisable at year-end ........ 749,948 400,158 861,221
========== ========== ===========
Options available for future grant ..... 2,183,624 2,752,806 2,672,832
---------- ---------- -----------
Weighted-average fair value of
options granted during the year:
PSP................................ $3.89 N/A $4.21
========== ===========
DRP................................ $5.85 $7.32 $15.69
========== ========== ===========
The following table summarizes information about stock options outstanding at
December 31, 1999:
Options Outstanding Options Exercisable
---------------------------------------------------------------- ---------------------------------
Weighted-
Average Weighted Weighted
Range of Number Remaining Average Number Average
Exercise Outstanding Contractual Exercise Exercisable Exercise
Prices At 12/31/99 Life Prices At 12/31/99 Prices
-------------------- -------------------- --------------------- ------------------ --------------- ----------------
$5.50 - $12.75 29,000 8.15 years $ 9.466 21,000 $ 9.381
$11.50 - $23.688 1,555,934 7.56 years $18.398 728,948 $17.343
------------ -----------
1,584,934 7.57 years $18.235 749,948 $17.120
============ ===========
F-33
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(9) Stock Option Plans (Continued)
Had compensation cost for the Company's performance stock plan been
determined consistent with SFAS No. 123, Accounting for Stock-Based
Compensation, the effect on the Company's pro forma net earnings and pro forma
earnings per share would be as follows (in thousands, except per share data):
1999 1998 1997
------------------------- ------------------------ -------------------------
As Reported Pro forma As Reported Pro forma As Reported Pro forma
------------- ---------- ------------ ---------- ------------- -----------
Net earnings: (available for
Common)...................... $82,569 $81,573 $82,096 $81,554 $80,409 $80,018
Net earnings per share
Basic...................... $ 2.01 $ 1.99 $ 1.97 $ 1.95 $ 1.92 $ 1.92
Diluted.................... $ 2.01 $ 1.98 $ 1.95 $ 1.95 $ 1.91 $ 1.90
(10) Construction Program and Jointly-Owned Plants
The Company's construction expenditures for 1999 were approximately
$95.3 million, including expenditures on jointly-owned projects. The Company's
proportionate share of expenses for the jointly-owned plants is included in
operating expenses in the consolidated statements of earnings.
At December 31, 1999, the Company's interests and investments in
jointly-owned generating facilities are:
Construction
Plant in Accumulated Work in Composite
Station (Fuel Type) Service Depreciation Progress Interest
- ------------------- -------- ------------ ------------ ---------
(In thousands)
San Juan Generating Station (Coal).... $704,458 $330,457 $ 5,088 46.3%
Palo Verde Nuclear Generating
Station (Nuclear)*.................. $197,369 $ 49,284 $18,818 10.2%
Four Corners Power Plant
Units 4 and 5 (Coal) ............... $117,799 $ 66,755 $ 1,788 13.0%
- -----------
* Includes the Company's interest in PVNGS Unit 3, the Company's interest
in common facilities for all PVNGS units and the Company's owned
interests in PVNGS Units 1 and 2.
F-34
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(10) Construction Program and Jointly-Owned Plants (Continued)
San Juan Generating Station ("SJGS")
The Company operates and jointly owns SJGS. At December 31, 1999, SJGS
Units 1 and 2 are owned on a 50% shared basis with Tucson Electric Power
Company, Unit 3 is owned 50% by the Company, 41.8% by Southern California Public
Power Authority ("SCPPA") and 8.2% by Tri-State Generation and Transmission
Association, Inc. Unit 4 is owned 38.457% by the Company, 28.8% by M-S-R Public
Power Agency, ("M-S-R"), 10.04% by the City of Anaheim, California, 8.475% by
the City of Farmington, 7.2% by the County of Los Alamos, and 7.028% by Utah
Associated Municipal Power Systems.
Palo Verde Nuclear Generating Station
The Company is a participant in the three 1,270 MW units of PVNGS, also
known as the Arizona Nuclear Power Project, with Arizona Public Service Company
("APS") (the operating agent), Salt River Project, El Paso Electric Company ("El
Paso"), Southern California Edison Company, SCPPA and The Department of Water
and Power of the City of Los Angeles. The Company has a 10.2% undivided interest
in PVNGS, with portions of its interests in Units 1 and 2 held under leases.
(See Note 11 for additional discussion.)
(11) Commitments and Contingencies
Long-Term Power Contracts
The Company has a power purchase contract with Southwestern Public
Service Company ("SPS") which originally provided for the purchase of up to 200
MW, expiring in May 2011. The Company may reduce its purchases from SPS by 25 MW
annually upon three years' notice. The Company provided such notice to reduce
the purchase by 25 MW in 1999 and by an additional 25 MW in 2000. The Company
has 39 MW of contingent capacity obtained from El Paso under a transmission
capacity for generation capacity trade arrangement that increases to 70 MW from
1999 through 2003. In addition, the Company is interconnected with various
utilities for economy interchanges and mutual assistance in emergencies.
In 1996, the Company entered into a long-term power purchase agreement
("PPA") with Cobisa-Person Limited Partnership ("PLP") to purchase approximately
100 MW of unit contingent peaking capacity from a gas turbine generating unit
for a period of 20 years, with an option to renew for an additional five years.
The agreement calls for PLP to construct and operate a gas turbine generating
unit located on the Company's retired Person Generating Station site in
Albuquerque, New Mexico.
F-35
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(11) Commitments and Contingencies (Continued)
In 1998, the PPA was amended to change the maximum capacity the Company
was obligated to take to 132 MW and to change the commercial operation date from
May 1999 to May 2000. Primary fuel for the gas turbine generating unit will be
natural gas, which will be provided by the Company. In addition, the unit will
have the capability to utilize low sulfur fuel oil in the event natural gas is
not available.
The Company has been actively trading in the wholesale power market and
has entered into and anticipates that it will continue to enter into power
purchases to accommodate its trading activity.
Construction Commitment
The Company has committed to purchase a combustion turbine for $36.0
million. In February 2000, the Company made a 10% deposit toward the purchase
price. The turbine is for a planned power generation plant with an estimated
cost of approximately $63.0 million for which a contract has not been finalized.
The planned plant is part of the Company's ongoing competitive strategy of
increasing generation capacity over time.
Plains Acquisition
The Company and Tri-State Generation and Transmission Cooperatives,
Inc. ("Tri-State") entered into an asset sale agreement dated September 9, 1999,
pursuant to which Tri-State has agreed to sell certain assets consisting
primarily of transmission assets, a fifty percent interest in an inactive power
plant located near Albuquerque, and an office building to the Company. The
purchase price is $13.2 million, subject to adjustment at the time of closing.
The asset sale agreement contains standard covenants and conditions for this
type of agreement. Currently the Company anticipates that the purchase will be
completed by approximately the fall of 2000.
New Customer Billing System
On November 30, 1998, the Company implemented a new customer billing
system. Due to a significant number of problems associated with the
implementation of the new billing system, the Company was unable to generate
appropriate bills for all its customers through the first quarter of 1999 and
was unable to analyze delinquent accounts until November 1999.
Because of the implementation issues associated with the new billing
system, the Company estimated retail gas and electric revenues through July
1999. Beginning with August 1999, the Company was able to determine actual
revenues for all prior periods affected and began reconciling with previously
estimated revenues. In December 1999, the Company completed its reconciliation
of system revenues. As a result, 1999 revenues represented actual revenues as
determined by the new billing system. The resulting reconciliation did not
materially impact recorded revenues. However, a significant number of individual
accounts required corrections.
F-36
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(11) Commitments and Contingencies (Continued)
As a result of the delay of normal collection activities, the Company
incurred a significant increase in delinquent accounts, many of which occurred
with customers that no longer have active accounts with the Company. As a
result, the Company significantly increased its bad debt accrual throughout
1999.
The following is a summary of the allowance for doubtful accounts during
1999, 1998 and 1997:
1999 1998 1997
-------- ------- -------
(In thousands)
Allowance for doubtful accounts beginning
of year......................................... $ 836 $ 783 $ 709
Bad debt accrual.................................. 11,496 3,325 3,378
Less: Write off (adjustments) of
uncollectible accounts .................... (172) 3,272 3,304
-------- ------- -------
Allowance for doubtful accounts, end of year ..... $12,504 $ 836 $ 783
======== ======= =======
Bad debt accruals for 1999 represent management's best estimate of
potential uncollectible accounts based upon information available at December
31, 1999. The Company will make every reasonable effort to collect all amounts
owed from delinquent customers. As new data becomes available from these
efforts, management will re-evaluate the adequacy of the bad debt reserve. Any
required change to the allowance for doubtful accounts will be reflected in
operating results in the period new information becomes available. The Company
will also provide additional disclosures as collection efforts progress over
time.
Rate Case Settlement
On August 25, 1999, the PRC issued an order approving the rate case
settlement resulting from the NMPUC's final order of November 30, 1998. The PRC
ordered the Company to reduce its electric rates by $34.0 million annually
retroactive to July 30, 1999. In addition, the order includes a rate freeze
until electric competition is fully implemented in New Mexico or until January
1, 2003. The settlement will reduce annual revenues by an estimated $37.0
million based on expected customer growth.
PVNGS Liability and Insurance Matters
The PVNGS participants have insurance for public liability resulting from
nuclear energy hazards to the full limit of liability under Federal law. This
potential liability is covered by primary liability insurance provided by
commercial insurance carriers in the amount of $200 million and the balance by
an industry-wide retrospective assessment program. If losses at any nuclear
power plant covered by the programs exceed the primary liability insurance
limit, the Company could be assessed retrospective premium adjustments. The
maximum assessment per reactor under the program for each nuclear incident is
approximately $88 million, subject to an annual limit of $10 million per reactor
per incident. Based upon the Company's 10.2% interest in the three PVNGS units,
the Company's maximum potential assessment per incident for all three units is
F-37
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(11) Commitments and Contingencies (Continued)
approximately $27.0 million, with an annual payment limitation of $3 million per
incident. If the funds provided by this retrospective assessment program prove
to be insufficient, Congress could impose revenue raising measures on the
nuclear industry to pay claims. The United States Nuclear Regulatory Commission
and Congress are reviewing the related laws. The Company cannot predict whether
or not Congress will change the law. However, certain changes could possibly
trigger "Deemed Loss Events" under the Company's PVNGS leases, absent waiver by
the lessors.
The PVNGS participants maintain "all-risk" (including nuclear hazards)
insurance for nuclear property damage to, and decontamination of, property at
PVNGS in the aggregate amount of $2.75 billion as of January 1, 2000. The
Company is a member of an industry mutual insurer which provides both the
"all-risk" and increased cost of generation insurance to the Company. In the
event of adverse losses experienced by this insurer, the Company is subject to
an assessment. The Company's maximum share of any assessment is approximately
$2.6 million per year.
PVNGS Decommissioning Funding
The Company has a program for funding its share of decommissioning costs
for PVNGS. The nuclear decommissioning funding program is invested in equities
and fixed income instruments in qualified and non-qualified trusts. The results
of the 1998 decommissioning cost study indicated that the Company's share of the
PVNGS decommissioning costs excluding spent fuel disposal will be approximately
$163.1 million (in 1999 dollars).
The Company funded an additional $3.1 million, $3.0 million and $2.1
million in 1999, 1998 and 1997, respectively, into the qualified trust funds.
The estimated market value of the trusts at the end of 1999 was approximately
$51.8 million.
Nuclear Spent Fuel and Waste Disposal
Pursuant to the Nuclear Waste Policy Act of 1982, as amended in 1987 (the
"Waste Act"), the United States Department of Energy ("DOE") is obligated to
accept and dispose of all spent nuclear fuel and other high-level radioactive
wastes generated by all domestic power reactors. Under the Waste Act, DOE was to
develop the facilities necessary for the storage and disposal of spent nuclear
fuel and to have the first such facility in operation by 1998. DOE has announced
that such a repository now cannot be completed before 2010.
The operator of PVNGS has capacity in existing fuel storage pools at
PVNGS which, with certain modifications, could accommodate all fuel expected to
be discharged from normal operation of PVNGS through 2002, and believes it could
augment that storage with the new facilities for on-site dry storage of spent
fuel for an indeterminate period of operation beyond 2002, subject to obtaining
any required governmental approvals. The Company currently estimates that it
will incur approximately $41.0 million (in 1999 dollars) over the life of PVNGS
F-38
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(11) Commitments and Contingencies (Continued)
for its share of the costs related to the on-site interim storage of spent
nuclear fuel. The Company accrues these costs as a component of fuel expense,
meaning the charges are accrued as the fuel is burned. During 1999, the Company
expensed approximately $1.0 million for on-site interim nuclear fuel storage
costs related to nuclear fuel burned prior to 2000. The operator of PVNGS
currently believes that spent fuel storage or disposal methods will be available
for use by PVNGS to allow its continued operation beyond 2002.
Contingencies
There are various claims and lawsuits pending against the Company and
certain of its subsidiaries. The Company is also subject to Federal, state and
local environmental laws and regulations, and is currently participating in the
investigation and remediation of numerous sites. In addition, the Company
periodically enters into financial commitments in connection with business
operations. It is not possible at this time for the Company to determine fully
the effect of all litigation on its consolidated financial statements. However,
the Company has recorded a liability where an outcome of such litigation can be
estimated and where an outcome is considered probable. The Company does not
expect that any known lawsuits, environmental costs and commitments will have a
material adverse effect on its financial condition or results of operations.
(12) Environmental Issues
The normal course of operations of the Company necessarily involves
activities and substances that expose the Company to potential liabilities under
laws and regulations protecting the environment. Liabilities under these laws
and regulations can be material and in some instances may be imposed without
regard to fault, or may be imposed for past acts, even though such past acts may
have been lawful at the time they occurred. Sources of potential environmental
liabilities include (but are not limited to) the Federal Comprehensive
Environmental Response Compensation and Liability Act of 1980 and other similar
statutes.
The Company records its environmental liabilities when site assessments
and/or remedial actions are probable and a range of reasonably likely cleanup
costs can be estimated. The Company reviews its sites and measures the liability
quarterly, by assessing a range of reasonably likely costs for each identified
site using currently available information, including existing technology,
presently enacted laws and regulations, experience gained at similar sites, and
the probable level of involvement and financial condition of other potentially
responsible parties. These estimates include costs for site investigations,
remediation, operations and maintenance, monitoring and site closure. Unless
there is a probable amount, the Company, records the lower end of this
reasonably likely range of costs (classified as other long-term liabilities at
undiscounted amounts).
The Company's recorded estimated minimum liability to remediate its
identified sites is $8.3 million. The ultimate cost to clean up the Company's
identified sites may vary from its recorded liability due to numerous
uncertainties inherent in the estimation process, such as: the extent and nature
of contamination; the scarcity of reliable data for identified sites; and the
time periods over which site remediation is expected to occur. The Company
believes that, due to these uncertainties, it is remotely possible that cleanup
costs could exceed its recorded liability by up to $30.3 million. The upper
limit of this range of costs was estimated using assumptions least favorable to
the Company.
F-39
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(12) Environmental Issues (Continued)
Remediation of identified sites previously used in operations, used by
tenants or contaminated by former owners required spending of $4.4 million in
1999 and $1.0 million in 1998. In 2000, the Company anticipates spending $2.2
million for remediation and $6 million for control and prevention. The majority
of the December 31, 1999 environmental liability is expected to be paid over the
next five years, funded by cash generated from operations. Future environmental
obligations are not expected to have a material impact on the results of
operations or financial condition of the Company.
(13) Discontinued Operations
On August 4, 1998, the Company adopted a plan to discontinue the gas
trading operations of its Energy Services Business Unit. Accordingly, the gas
marketing operations of its Energy Services Business Unit are reported as
discontinued operations. Estimated losses on the disposal of the gas marketing
segment were $5.1 million (net of income tax benefit of $3.3 million), which
includes a provision for anticipated operating losses prior to disposal.
Operating losses of the discontinued operations prior to the date of
discontinuation were $7.4 million and $5.5 million in 1998 and 1997,
respectively. Such amounts include income tax benefits related to the losses
from discontinued operations of $4.8 million in 1998 and $3.6 million in 1997.
Total sales from the discontinued operations were $159.2 million and $114.7
million in 1998 and 1997, respectively. Prior to the decision to discontinue
non-utility operations, such total sales and income tax benefits were included
in operating revenues and operating expenses in the consolidated statement of
earnings.
F-40
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 1999, 1998 and 1997
(14) New and Proposed Accounting Standards
Decommissioning: The Staff of the Securities and Exchange Commission
("SEC") has questioned certain of the current accounting practices of the
electric industry regarding the recognition, measurement and classification of
decommissioning costs for nuclear generating stations in financial statements of
electric utilities. In response to these questions, the Financial Accounting
Standards Board ("FASB") has a project on its agenda to review the accounting
for closure and removal costs, including decommissioning of nuclear power
plants. If current electric industry accounting practices for nuclear power
plant decommissioning are changed, the estimated cost for decommissioning could
be recorded as a liability with recognition of an increase in the cost of the
related nuclear power plant. The Company does not believe that such changes, if
required, would have a material adverse effect on results of operations.
EITF Issue 99-14, Recognition of Impairment Losses on Firmly Committed
Executory Contracts: The EITF has added an issue to its agenda to address
impairment of leased assets. A significant portion of the Company's nuclear
generating assets are held under operating leases. Based on the alternative
accounting methods being explored by the EITF, the related financial impact of
the future adoption of EITF Issue No. 99-14 should not have a material adverse
effect on results of operations. However, a complete evaluation of the financial
impact from the future adoption of EITF Issue No. 99-14 will be undeterminable
until EITF deliberations are completed and stranded cost recovery issues are
resolved.
Accounting for Derivative Instruments and Hedging Activities, SFAS 133:
SFAS 133 establishes accounting and reporting standards requiring that every
derivative instrument be recorded in the balance sheet as either an asset or
liability measured at its fair value. The Statement also requires that changes
in the derivatives' fair value be recognized currently in earnings unless
specific hedge accounting criteria are met. Special accounting for qualifying
hedges allows derivative gains and losses to offset related results on the
hedged item in the income statement, and requires that a company must formally
document, designate, and assess the effectiveness of transactions that receive
hedge accounting. The Company is in the process of reviewing and identifying all
financial instruments currently existing in the Company in compliance with the
provisions of SFAS 133. It is likely that the adoption of SFAS 133 will add
volatility to the Company's operating results and/or asset and liability
valuations reflecting the impact of mark-to-market accounting for commodity
contracts. In June 1999, FASB issued SFAS 137 to amend the effective date for
the compliance of SFAS 133 to January 1, 2001.
F-41
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
QUARTERLY OPERATING RESULTS
The unaudited operating results by quarters for 1999 and 1998 are as follows:
Quarter Ended
------------------------------------------------------
March 31 June 30 September 30 December 31
------------- ----------- ------------ -----------
(In thousands, except per share amounts)
1999:
Operating Revenues........................... $272,818 $261,371 $ 340,604 $ 282,750
Operating Income............................. 35,068 29,247 30,275 25,489
Earnings from Continuing Operations.......... 23,130 18,172 21,401 16,911
Net Earnings (1)............................. 26,671 18,172 21,401 16,911
Net Earnings per share from Continuing
Operations................................ 0.55 0.44 0.52 0.41
Net Earnings per Share (Basic)............... 0.64 0.44 0.52 0.41
Net Earnings per Share (Diluted)............. 0.63 0.44 0.52 0.41
1998:
Operating Revenues........................... 282,560 230,478 320,438 258,969
Operating Income............................. 36,626 26,042 47,446 25,535
Earnings from Continuing Operations.......... 25,561 16,497 34,656 18,405
Net Earnings (2)............................. 21,214 14,778 31,989 14,701
Net Earnings per share from Continuing
Operations................................ 0.61 0.39 0.83 0.44
Net Earnings per Share (Basic)............... 0.50 0.35 0.76 0.36
Net Earnings per Share (Diluted)............. 0.50 0.35 0.76 0.34
In the opinion of management of the Company, all adjustments
(consisting of normal recurring accruals) necessary for a fair statement of the
results of operations for such periods have been included.
- -------------------
(1) Effective January 1, 1999, the Company adopted EITF Issue No. 98-10,
Accounting for Contracts Involved in Energy Trading and Risk Management
Activities. The effect of the initial application of EITF Issue No.
98-10 was reported as a cumulative effect of a change in accounting
principle which increased the Company's consolidated net income by
approximately $3.5 million (after related income tax expense of
approximately $2.3 million), or $.08 per common share.
(2) On August 4, 1998, the Company adopted a plan to discontinue the gas
trading operations of its Energy Services Business Unit. As a result,
estimated losses of $1.4 million ($0.03 per common share) and $3.7
million ($0.09 per common share) for the third quarter and the fourth
quarter, respectively, were recognized. (See note 13 of the notes to
consolidated financial statements.) In addition, certain prior periods
amounts have been restated.
F-42
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
COMPARATIVE OPERATING STATISTICS
1999 1998 1997 1996 1995
---------- ----------- ---------- ----------- ----------
Electric Service
Energy Sales--KWh (in thousands):
Residential.................................. 2,027,099 2,007,852 1,976,434 1,892,290 1,795,371
Commercial................................... 2,980,935 2,888,539 2,841,831 2,698,087 2,578,243
Industrial................................... 1,559,155 1,571,824 1,556,264 1,505,801 1,434,974
Other ultimate customers..................... 236,394 271,659 160,370 310,118 220,777
---------- ----------- ---------- ----------- ----------
Total sales to ultimate customers.......... 6,803,583 6,739,874 6,534,899 6,406,296 6,029,365
Sales for resale............................. 11,171,621 8,782,315 6,785,643 4,575,220 2,590,513
---------- ----------- ---------- ----------- ----------
Total KWh sales............................ 17,975,204 15,522,189 13,320,542 10,981,516 8,619,878
========== =========== ========== =========== ==========
Electric Revenues (in thousands):
Residential.................................. $ 184,088 $ 187,681 $ 184,813 $ 177,220 $ 168,633
Commercial................................... 238,830 241,968 237,629 226,146 218,222
Industrial................................... 85,828 88,644 86,927 83,651 79,964
Other ultimate customers..................... 13,777 18,124 10,135 20,804 18,749
---------- ----------- ---------- ----------- ----------
Total revenues to ultimate customers....... 522,523 536,417 519,504 507,821 485,568
Sales for resale............................. 365,368 274,979 185,334 121,329 80,949
---------- ----------- ---------- ----------- ----------
Total revenues from energy sales........... 887,891 811,396 704,838 629,150 566,517
Miscellaneous electric revenues.............. 24,086 23,808 17,600 16,489 17,767
---------- ----------- ---------- ----------- ----------
Total electric revenues.................... $ 911,977 $ 835,204 $ 722,438 $ 645,639 $ 584,284
========== =========== ========== =========== ==========
Customers at Year End:
Residential.................................. 321,949 319,415 311,314 304,900 296,821
Commercial................................... 38,435 37,652 36,942 36,292 35,390
Industrial................................... 375 363 363 375 374
Other ultimate customers..................... 625 665 637 632 598
---------- ----------- ---------- ----------- ----------
Total ultimate customers................... 361,384 358,095 349,256 342,199 333,183
Sales for Resale............................. 83 83 66 56 37
---------- ----------- ---------- ----------- ----------
Total customers............................ 361,467 358,178 349,322 342,255 333,220
========== =========== ========== =========== ==========
Reliable Net Capability--KW.................... 1,521,000 1,506,000 1,506,000 1,506,000 1,506,000
Coincidental Peak Demand--KW................... 1,291,000 1,313,000 1,209,000 1,217,000 1,247,000
Average Fuel Cost per Million BTU.............. $ 1.3169 $ 1.2433 $ 1.2318 $ 1.2735 $ 1.3177
BTU per KWh of Net Generation.................. 10,490 10,784 10,927 10,768 10,811
Water Service**
Water Sales--Gallon (in thousands)........... - - - - 1,616,544
Revenues (in thousands)...................... - - - - $ 6,196
Customers at Year End........................ - - - - 23,752
* Due to the provision for the loss associated with the M-S-R contingent power
purchase contract recognized in 1992, operating revenues were reduced by
$7.3 million for 1995.
** On July 3, 1995, the Company sold its water utility division. Water
Service's comparative operating statistics for 1995 are through this date.
F-43
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
COMPARATIVE OPERATING STATISTICS
1999 1998 1997 1996 1995
---------- ---------- ---------- ---------- ----------
Gas Throughput--Decatherms (in thousands)
PNMGS:
Residential............................. 29,309 30,258 30,755 27,387 25,865
Commercial.............................. 10,134 10,387 10,644 9,310 8,864
Industrial.............................. 2,338 1,553 1,280 2,136 661
Public authorities...................... 2,902 3,427 4,153 2,591 2,411
Irrigation.............................. 1,382 1,869 1,593 1,418 1,245
Sales for resale........................ 1,181 1,205 1,233 3,094 1,266
Off-system sales........................ 1,073 1,889 1,179 5,745 1,176
Unbilled................................ 3,784 (1,343) (202) 1,405 (1,764)
---------- ---------- ---------- ---------- ----------
PNMGS sales............................. 52,103 49,245 50,635 53,086 39,724
Transportation throughput............... 40,161 36,413 33,975 47,010 49,136
---------- ---------- ---------- ---------- ----------
PNMGS throughput......................... 92,264 85,658 84,610 100,096 88,860
Gathering Company:
Spot market sales....................... - - - - 39
Transportation throughput............... - - - - 20,695
---------- ---------- ---------- ---------- ----------
Total throughput................... 92,264 85,658 84,610 100,096 109,594
========== ========== ========== ========== ==========
Gas Revenues (in thousands)
PNMGS:
Residential............................. $ 148,968 $ 161,153 $ 187,563 $ 129,911 $ 125,290
Commercial.............................. 36,528 42,680 50,502 33,022 32,328
Industrial.............................. 8,550 4,887 4,536 5,179 1,873
Public authorities...................... 9,782 12,610 17,577 8,018 7,939
Irrigation.............................. 4,229 5,780 5,041 3,252 3,077
Sales for resale........................ 2,530 3,596 4,465 2,106 3,114
Off-system sales........................ 2,357 3,816 1,926 14,352 1,885
Imbalance penalties..................... 1,182 1,416 1,273 1,231 1,786
Unbilled................................ 4,107 (955) (2,172) 2,678 (2,430)
---------- ---------- ---------- ---------- ----------
Revenues from gas sales................. 218,233 234,983 270,711 199,749 174,862
Transportation.......................... 12,390 13,464 14,172 17,215 18,532
Liquids................................. 1,867 1,463 4,451 7,608 12,782
Other................................... 4,221 6,065 5,435 2,729 3,606
---------- ---------- ---------- ---------- ----------
PNMGS operating revenues................ 236,711 255,975 294,769 227,301 209,782
Gathering Company:
Spot market sales....................... - - - - 42
Transportation.......................... - - - - 3,640
Imbalance penalties..................... - - - - 418
Processing Company:
Liquids revenue......................... - - - - 632
Processing fees......................... - - - - 3,471
---------- ---------- ---------- ---------- ----------
Total operating revenues........... $ 236,711 $ 255,975 $ 294,769 $ 227,301 $ 217,985
========== ========== ========== ========== ==========
Customers at Year End
PNMGS:
Residential............................. 390,428 383,292 375,032 367,025 358,822
Commercial.............................. 32,116 32,004 31,560 30,757 30,493
Industrial.............................. 51 55 50 54 59
Public authorities...................... 2,547 2,429 2,735 2,462 2,444
Irrigation.............................. 1,026 1,078 1,027 1,076 886
Sales for resale........................ 3 3 3 3 2
Gas choice.............................. 112 112 - - -
Transportation.......................... 32 29 31 36 38
---------- ---------- ---------- ---------- ----------
Total customers.................... 426,315 419,002 410,438 401,413 392,744
========== ========== ========== ========== ==========
- ----------
On June 30, 1995, the Company sold substantially all of the gas gathering and
processing assets of the Company and its gas subsidiaries. Comparative operating
statistics for Gathering Company and Processing Company are through this date.
F-44
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY
Reference is hereby made to "Election of Directors" in the Company's
Proxy Statement relating to the annual meeting of stockholders to be held on
June 6, 2000 (the "2000 Proxy Statement"), to PART I, SUPPLEMENTAL ITEM -
"EXECUTIVE OFFICERS OF THE COMPANY" and "Other Matters" - "Section 16(a)
Beneficial Ownership Reporting Compliance" in the 2000 Proxy Statement.
ITEM 11. EXECUTIVE COMPENSATION
Reference is hereby made to "Executive Compensation" in the 2000 Proxy
Statement.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Reference is hereby made to "Voting Information", "Election of Directors"
and "Stock Ownership of Certain Executive Officers" in the 2000 Proxy Statement.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Reference is hereby made to the 2000 Proxy Statement for such disclosure,
if any, as may be required by this item.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a) - 1. See Index to Financial Statements under Item 8.
(a) - 2. Financial Statement Schedules for the years 1999, 1998,
and 1997 are omitted for the reason that they are not
required or the information is otherwise supplied.
(a) - 3-A. Exhibits Filed:
Exhibit No. Description
----------- -----------
3.2 By-laws of Public Service Company of New Mexico With All
Amendments to and including February 8, 2000
E-1
Exhibit No. Description
----------- -----------
4.6.1 Third Supplement, dated as of October 1, 1999 to Indenture
dated as of March 11, 1998, between Public Service Company of
New Mexico and The Chase Manhattan Bank, as Trustee
10.11.3 Amendment No. 3 to the San Juan Unit 4 Early Purchase and
Participation Agreement between Public Service Company of New
Mexico and M-S-R Public Power Agency, dated as of October 27,
1999
10.12.1 Amendment No. 1 to the Amended and Restated San Juan Unit 4
Purchase and Participation Agreement between Public Service
Company of New Mexico and The Incorporated County of Los
Alamos, New Mexico, dated October 27, 1999
10.13 Amendment No. 2 to the San Juan Unit 4 Purchase Agreement and
Participation Agreement between Public Service Company of New
Mexico and The City of Farmington, New Mexico, dated October
27, 1999
10.32** Supplemental Employee Retirement Agreements dated August 4,
1989, between Public Service Company of New Mexico and John
T. Ackerman and Max Maerki (refiled)
10.36.1 Amendment No. 1 to the San Juan Unit 4 Purchase and
Participation Agreement between Public Service Company of New
Mexico and The City of Anaheim, California, dated October 27,
1999
10.38.1 Amendment No. 1 to the Restated and Amended San Juan Unit 4
Purchase and Participation Agreement between Public Service
Company of New Mexico and Utah Associated Municipal Power
Systems, dated October 27, 1999
23.1 Consent of Arthur Andersen LLP.
27 Financial Data Schedule.
- ----------
** Designates each management contract or compensatory plan or
arrangement required to be identified pursuant to paragraph 3 of
Item 14(a) of Form 10 -K.
(a) - 3-B. Exhibits Incorporated By Reference:
E-2
In addition to those Exhibits shown above, the Company hereby
incorporates the following Exhibits pursuant to Exchange Act Rule 12b-32 and
Regulation S-K section 10, paragraph (d) by reference to the filings set forth
below:
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
Articles of Incorporation and By-laws
3.1 Restated Articles of Incorporation of the 4-(b) to Registration Statement 2-99990
Company, as amended through May 10, No. 2-99990 of the Company.
1985.
Instruments Defining the Rights of Security Holders, Including Indentures
4.1 Indenture of Mortgage and Deed of 4-(d) to Registration Statement 2-99990
Trust dated as of June 1, 1947, between No. 2-99990 of the Company.
the Company and The Bank of New York (formerly
Irving Trust Company), as Trustee, together
with the Ninth Supplemental Indenture dated as
of January 1, 1967, the Twelfth Supplemental
Indenture dated as of September 15, 1971, the
Fourteenth Supplemental Indenture dated as of
December 1, 1974 and the Twenty- Second
Supplemental Indenture dated as of October 1,
1979 thereto relating to First Mortgage Bonds
of the Company.
4.2 Portions of sixteen supplemental 4-(e) to Registration Statement 2-99990
Indentures to the Indenture of Mortgage No. 2-99990 of the Company.
and Deed of Trust dated as of June 1,
1947, between the Company and The Bank of New
York (formerly Irving Trust Company), as
Trustee, relevant to the declaration or
payment of dividends or the making of other
distributions on or the purchase by the
Company of shares of the Company's Common
Stock.
E-3
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
4.3 Fifty-third Supplemental Indenture, dated 4.3 to the Company's Quarterly 1-6986
as of March 11, 1998, supplemental to Report on Form 10-Q for the
Indenture of Mortgage and Deed of Trust, quarter ended March 31, 1998.
dated as of June 1, 1947, between the
Company and The Bank of New York
(formerly Irving Trust Company), as
trustee.
4.4 Indenture (for Senior Notes), dated as of 4.4 to the Company's 1-6986
March 11, 1998, between the Company and The Quarterly Report on Form
Chase Manhattan Bank, as Trustee. 10-Q for the quarter ended March
31, 1998.
4.5 First Supplemental Indenture, dated as 4.5 to the Company's 1-6986
of March 11, 1998, supplemental to Quarterly Report on Form
Indenture, dated as of March 11, 1998, 10-Q for the quarter ended March
Between the Company and The Chase 31, 1998.
Manhattan Bank, as Trustee.
4.6 Second Supplemental Indenture, dated 4.6 to the Company's Quarterly 1-6986
as of March 11, 1998, supplemental to Report on Form
Indenture, dated as of March 11, 1998, 10-Q for the quarter ended March
Between the Company and The Chase 31, 1998.
Manhattan Bank, as Trustee.
4.7 Indenture (for Senior Notes), dated as of 4.1 to Registration 33-53367
August 1, 1998, between the Company Statement No. 33-53367 of the
and The Chase Manhattan Bank, as Company.
Trustee.
4.8 First Supplemental Indenture, dated 4.3 to the Company's 1-6986
August 1, 1998, supplemental to Current Report on Form 8-K
Indenture, dated as of August 1, dated August 7, 1998.
1998, between the Company and the
Chase Manhattan Bank, as Trustee.
Material Contracts
10.1 Supplemental Indenture of Lease dated as 4-D to Registration Statement No. 2-26116
of July 19, 1966 between the Company 2-26116 of the Company.
and other participants in the Four Corners
Project and the Navajo Indian Tribal
Council.
E-4
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.1.1 Amendment and Supplement No. 1 to 10.1.1 to Annual Report of the 1-6986
Supplemental and Additional Indenture of Registrant on Form 10-K for fiscal
Lease dated April 25, 1985 between the year ended December 31, 1995.
Navajo Tribe of Indians and Arizona
Public Service Company, El Paso Electric
Company, Public Service Company of
New Mexico, Salt River Project
Agricultural Improvement and Power
District, Southern California Edison
Company, and Tucson Electric Power
Company (refiled).
10.2 Fuel Agreement, as supplemented, dated 4-H to Registration Statement No. 2-35042
as of September 1, 1966 between Utah 2-35042 of the Company.
Construction & Mining Co. and the
participants in the Four Corners Project
including the Company.
10.3 Fourth Supplement to Four Corners Fuel 10.3 to Annual Report of the 1-6986
Agreement No. 2 effective as of January Registrant on Form 10-K for fiscal
1, 1981, between Utah International Inc. year ended December 31, 1991.
and the participants in the Four Corners
Project, including the Company.
10.4 Contract between the United States and 5-L to Registration Statement No. 2-41010
the Company dated April 11, 1968, for 2-41010 of the Company.
furnishing water.
10.4.1 Amendatory Contract between the United 5-R to Registration Statement No. 2-60021
States and the Company dated September 2-60021 of the Company.
29, 1977, for furnishing water.
10.8 Arizona Nuclear Power Project 5-T to Registration Statement 2-50338
Participation Agreement among the No. 2-50338 of the Company.
Company and Arizona Public Service
Company, Salt River Project Agricultural
Improvement and Power District, Tucson
Gas & Electric Company and El Paso
Electric Company, dated August 23, 1973.
10.8.1 Amendments No. 1 through No. 6 to 10.8.1 to Annual Report of the 1-6986
Arizona Nuclear Power Project Registrant on Form 10-K for
Participation Agreement. fiscal year ended December 31,
1991.
10.8.2 Amendment No. 7 effective April 1, 10.8.2 to Annual Report of the 1-6986
1982, to the Arizona Nuclear Power Registrant on Form 10-K for
Project Participation Agreement (refiled). fiscal year ended December 31,
1991.
E-5
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.8.3 Amendment No. 8 effective September 12, 10.58 to Annual Report of the 1-6986
1983, to the Arizona Nuclear Power Registrant on Form 10-K for
Project Participation Agreement (refiled). fiscal year ended December 31,
1993.
10.8.4 Amendment No. 9 to Arizona Nuclear 10.8.4 to Annual Report of the 1-6986
Power Project Participation Agreement Registrant on Form 10-K for
dated as of June 12, 1984 (refiled). fiscal year ended December 31,
1994.
10.8.5 Amendment No. 10 dated as of November 10.8.5 to Annual Report of the 1-6986
21, 1985 and Amendment No. 11 dated as Registrant on Form 10-K for
of June 13, 1986 and effective January 10, fiscal year ended December 31,
1987 to Arizona Nuclear Power Project 1994.
Participation Agreement (refiled).
10.8.7 Amendment No. 12 to Arizona Nuclear 19.1 to the Company's Quarterly 1-6986
Power Project Participation Agreement Report on Form 10-Q for the
dated June 14, 1988, and effective quarter ended September 30, 1990.
August 5, 1988.
10.8.8 Amendment No. 13 to the Arizona 10.8.10 to Annual Report of 1-6986
Nuclear Power Project Participation Registrant on Form 10-K for the
Agreement dated April 4, 1990, and fiscal year ended December 31,
effective June 15, 1991. 1990.
10.9 Coal Sales Agreement executed August 18, 10.9 to Annual Report of the 1-6986
1980 among San Juan Coal Company, Registrant on Form 10-K for
the Company and Tucson Electric fiscal year ended December 31,
Power Company, together with 1991.
Amendments No. One, Two, Four, and
Six thereto.
10.9.1 Amendment No. Three to Coal Sales 10.9.1 to Annual Report of the 1-6986
Agreement dated April 30, 1984 among Registrant on Form 10-K for
San Juan Coal Company, the Company fiscal year ended December 31,
and Tucson Electric Power Company. 1994 (confidentiality treatment
was requested at the time of
filing the Annual Report of the
Registrant on Form 10-K for
fiscal year ended December 31,
1984; exhibit was not filed
therewith based on the same
confidentiality request).
E-6
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.9.2 Amendment No. Five to Coal Sales 10.9.2 to Annual Report of the 1-6986
Agreement dated May 29, 1990 among Registrant on Form 10-K for
San Juan Coal Company, the Company fiscal year ended December 31,
and Tucson Electric Power Company. 1991 (confidentiality treatment
was requested as to portions of
this exhibit, and such portions
were omitted from the exhibit
filed and were filed separately
with the Securities and Exchange
Commission).
10.9.3 Amendment No. Seven to Coal Sales 19.3 to the Company's Quarterly 1-6986
Agreement, dated as of July 27, 1992 Report on Form 10-Q for the
among San Juan Coal Company, the quarter ended September 30, 1992
Company and Tucson Electric Power (confidentiality treatment was
Company. requested as to portions of this
exhibit, and such portions were
omitted from the exhibit filed
and were filed separately with
the Securities and Exchange
Commission).
10.9.4 First Supplement to Coal Sales 19.4 to the Company's Quarterly 1-6986
Agreement, dated July 27, 1992 among Report on Form 10-Q for the
San Juan Coal Company, the Company quarter ended September 30, 1992
and Tucson Electric Power Company. (confidentiality treatment was
requested as to portions of this
exhibit, and such portions were
omitted from the exhibit as of
filed and were filed separately
with the Securities and Exchange
Commission).
10.9.5 Amendment No. Eight to Coal Sales 10.9.5 to Annual Report of the 1-6986
Agreement, dated as of September 1, Registrant on Form 10-K for
1995, among San Juan Coal Company, fiscal year ended December 31,
the Company and Tucson Electric 1995.
Power Company .
10.9.6 Amendment No. Nine to Coal Sales 10.9.6 to Annual Report of the 1-6986
Agreement, dated as of December 31, 1995, Registrant on Form 10-K for
among San Juan Coal Company, fiscal year ended December 31,
the Company and Tucson Electric Power 1996.
Company.
E-7
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.11 San Juan Unit 4 Early Purchase and 10.11 to the Company's Quarterly 1-6986
Participation Agreement dated as of Report on Form 10-Q for the
September 26, 1983 between the quarter ended March 31, 1994.
Company and M-S-R Public Power
Agency, and Modification No. 2 to the
San Juan Project Agreements dated
December 31, 1983 (refiled).
10.11.1 Amendment No. 1 to the Early Purchase 10.11.1 to Annual Report of the 1-6986
and Participation Agreement between Registrant on Form 10-K for
Public Service Company of New Mexico fiscal year ended December 31,
and M-S-R Public Power Agency, 1997.
executed as of December 16, 1987, for
San Juan Unit 4 (refiled).
10.12 Amended and Restated San Juan Unit 4 10.12 to Annual Report of the 1-6986
Purchase and Participation Agreement Registrant on Form 10-K for
dated as of December 28, 1984 between fiscal year ended December 31,
the Company and the Incorporated County 1994 (refiled).
of Los Alamos
10.14 Participation Agreement among the 10.14 to Annual Report of the 1-6986
Company, Tucson Electric Power Registrant on Form 10-K for
Company and certain financial institutions fiscal year ended December 31,
relating to the San Juan Coal Trust dated 1992.
as of December 31, 1981 (refiled).
10.16 Interconnection Agreement dated 10.16 to Annual Report of the 1-6986
November 23, 1982, between the Registrant on Form 10-K for
Company and Southwestern Public fiscal year ended December 31,
Service Company (refiled). 1992.
10.18* Facility Lease dated as of December 16, 10.18 to Annual Report of the 1-6986
1985 between The First National Bank Registrant on Form 10-K for
of Boston, as Owner Trustee, and Public fiscal year ended December 31,
Service Company of New Mexico 1995.
together with Amendments No. 1, 2 and 3
thereto (refiled).
10.18.4* Amendment No. 4 dated as of March 8, 10.18.4 to the Company's 1-6986
1995, to Facility Lease between Public Quarter Report on Form
Service Company of New Mexico and 10-Q for the quarter ended March
the First National Bank of Boston, dated 31, 1995.
as of December 16, 1985.
10.19 Facility Lease dated as of July 31, 1986, 10.19 to Annual Report of the 1-6986
between the First National Bank of Registrant on Form 10-K for
Boston, as Owner Trustee, and Public fiscal year ended December 31,
Service Company of New Mexico 1996.
together with Amendments No. 1, 2 and 3
thereto (refiled).
E-8
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.20* Facility Lease dated as of August 12, 10.20 to Annual Report of the 1-6986
1986, between The First National Bank Registrant on Form 10-K for
of Boston, as Owner Trustee, and Public fiscal year ended December 31,
Service Company of New Mexico 1996.
together with Amendments No. 1 and 2
thereto (refiled).
10.20.2 Amendment No. 2 dated as of April 10, 1987 to 10.20.2 to Annual Report of the 1-6986
Facility Lease dated as of August 12, 1986, as Registrant on Form 10-K for
amended, between The First National Bank of fiscal year ended December 31,
Boston, not in its individual capacity, but 1998.
solely as Owner Trustee under a Trust Agreement,
dated as of August 12, 1986, with MFS Leasing
Corp., Lessor and Public Service Company of New
Mexico, Lessee (refiled)
10.20.3 Amendment No. 3 dated as of March 8, 10.20.3 to the Company's 1-6986
1995, to Facility Lease between Public Quarterly Report on Form
Service Company of New Mexico and 10-Q for the quarter ended March
the First National Bank of Boston, 31, 1995.
dated as of August 12, 1986.
10.21 Facility Lease dated as of December 15, 10.21 to Annual Report of the 1-6986
1986, between The First National Bank Registrant on Form 10-K for
of Boston, as Owner Trustee, and Public fiscal year ended December 31,
Service Company of New Mexico (Unit 1 1996.
Transaction) together with Amendment No. 1
thereto (refiled).
10.22 Facility Lease dated as of December 15, 10.22 to Annual Report of the 1-6986
1986, between The First National Bank Registrant on Form 10-K for
of Boston, as Owner Trustee, and Public fiscal year ended December 31,
Service Company of New Mexico 1996.
Unit 2 Transaction) together with
Amendment No. 1 thereto (refiled).
10.23** Restated and Amended Public Service Company of 10.23 to Annual Report of the 1-6986
New Mexico Accelerated Management Performance Registrant on Form 10-K for
Plan (1988) (August 16, 1988) (refiled). fiscal year ended December 31,
1998.
10.23.1** First Amendment to Restated and Amended Public 10.23.1 to Annual Report of the 1-6986
Service Company of Registrant on Form 10-K for
New Mexico Accelerated Management Performance fiscal year ended December 31,
Plan (1988) (August 30, 1988) (refiled). 1998.
E-9
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.23.2** Second Amendment to Restated and Amended Public 10.23.2 to Annual Report of the 1-6986
Service Company of New Mexico Accelerated Registrant on Form 10-K
Management Performance Plan (1988)(December 29, for fiscal year
1989) (refiled). ended December 31, 1998.
10.23.4** Fourth Amendment to the Restated and Amended 10.23.4 to the Company's 1-6986
Public Service Company of New Mexico Quarterly Report on Form 10-Q
Accelerated Management Performance Plan, as for the quarter ended March 31,
amended effective December 7, 1998 1999.
10.24** Management Life Insurance Plan (July 10.24 to Annual Report of the 1-6986
1985) of the Company (refiled). Registrant on Form 10-K for
fiscal year ended December 31,
1995.
10.25.1** Second Restated and Amended Public 10.25.1 to Annual Report for the 1-6986
Service Company of New Mexico Registrant on Form 10-K for
Executive Medical Plan as amended on fiscal year ended December 31,
December 28, 1995. 1997.
10.27 Amendment No. 2 dated as of April 10, 10.53 to Annual Report of the 1-6986
1987, to the Facility Lease dated as of Registrant on Form 10-K for
August 12, 1986, between The First fiscal year ended December 31,
National Bank of Boston, as Owner 1987.
Trustee, and Public Service Company of New
Mexico. (Unit 2 Transaction.) (This is an
amendment to a Facility Lease which is
substantially similar to the Facility Lease
filed as Exhibit 28.1 to the Company's
Current Report on Form 8-K dated August 18,
1986.)
10.32.1** First Amendment to the Supplemental 10.32.1 to the Company's 1-6986
Employee Retirement Agreement. Quarterly Report on Form 10-Q
for the quarter ended September
30, 1998.
10.32.2** Second Amendment to the Supplemental Employee 10.32.2 to the Company's 1-6986
Retirement Agreement for Max H. Maerki, as Quarterly Report on Form 10-Q
amended effective December 7, 1998 for the quarter ended March 31,
1999.
10.32.3** First Amendment to the Supplemental Employee 10.32.3 to the Company's 1-6986
Retirement Agreement for John T. Ackerman, as Quarterly Report on Form 10-Q
amended effective December 7, 1998 for the quarter ended March 31,
1999.
E-10
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.34 Settlement Agreement between Public 10.48 to Annual Report of the 1-6986
Service Company of New Mexico and Registrant on Form 10-K for
Creditors of Meadows Resources, Inc. fiscal year ended December 31,
dated November 2, 1989. 1989.
10.34.1 First amendment dated April 24, 1992 to 19.1 to the Company's Quarterly 1-6986
the Settlement Agreement dated Report on Form 10-Q for the
November 2, 1989 among Public Service quarter ended September 30, 1992.
Company of New Mexico, the lender
parties thereto and collateral agent.
10.35 Amendment dated April 11, 1991 among 19.1 to the Company's Quarterly 1-6986
Public Service Company of New Mexico, Report on Form 10-Q for the
certain banks and Chemical Bank and quarter ended September 30, 1991.
Citibank, N.A., as agents for the banks.
10.36 San Juan Unit 4 Purchase and 19.2 to the Company's Quarterly 1-6986
Participation Agreement Public Service Report on Form 10-Q for the
Company of New Mexico and the City of quarter ended March 31, 1991.
Anaheim, California dated April 26, 1991.
10.38 Restated and Amended San Juan Unit 4 10.2.1 to the Company's 1-6986
Purchase and Participation Agreement Quarterly Report on Form 10-Q
between Public Service Company of for the quarter ended September
New Mexico and Utah Associated Municipal Power 30, 1993.
Systems.
10.40** First Restated and Amended Public Service 99.1 to Registration Statement 333-03303
Company of New Mexico Director Retainer Plan. No. 333-03303 filed May 8, 1996.
10.41 Waste Disposal Agreement, dated as of July 27, 19.5 to the Company's Quarterly 1-6986
1992 among San Juan Coal Company, the Company Report on Form 10-Q for the
and Tucson Electric Power Company. quarter ended September 30, 1992
(confidentiality treatment was
requested as to portions of this
exhibit, and such portions were
omitted from the exhibit and were
filed separately with the
Securities and Exchange
Commission).
10.42 Stipulation in the matter of the application 10.42 to Annual Report of the 1-6986
of Gas Company of New Mexico for an Registrant on Form 10-K for
order authorizing recovery of MDL costs fiscal year ended December 31,
through Rate Rider Number 8. 1992.
E-11
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.43** Description of certain Plans which include 10.43 to Annual Report of the 1-6986
executive officers as participants. Registrant on Form 10-K for
fiscal year ended December 31,
1992.
10.44.2** Second Restated and Amended Non-Union Severance 10.44.2 to the Company's 1-6986
Pay Plan of Public Service Company of New Mexico Quarterly Report on Form 10-Q
dated August 1, 1999 for the quarter ended September
30, 1999.
10.45** Second Amendment to the Public Service Company 10.45 to the Company's Quarterly 1-6986
of New Mexico Service Bonus Plan, as Report on Form 10-Q for the
amended effective December 7, 1998 quarter ended March 31, 1999.
10.47** Compensation Arrangement with Chief 10.3 to the Company's Quarterly 1-6986
Executive Officer. Report on Form 10-Q for the
quarter ended June 30, 1993.
10.47.1** Pension Service Adjustment Agreement 10.3.1 to the Company's 1-6986
for Benjamin F. Montoya. Quarterly Report on Form 10-Q
for the quarter ended September
30, 1993.
10.47.2** Severance Agreement for Benjamin F. 10.3.2 to the Company's 1-6986
Montoya. Quarterly Report on Form 10-Q
for the quarter ended September
30, 1993.
10.47.4** First Amendment to the Pension Service 10.47.4 to the Company's 1-6986
Adjustment Agreement for Benjamin F. Quarterly Report on Form 10-Q
Montoya. for the quarter ended June 30,
1998.
10.47.6** Second Amendment to the Pension Service 10.47.6 to the Company's 1-6986
Adjustment Agreement for Benjamin F. Montoya, as Quarterly Report on Form 10-Q
amended effective December 7, 1998 for the quarter ended March 31,
1999.
10.48** Public Service Company of New Mexico 10.4 to the Company's Quarterly 1-6986
OBRA `93 Retirement Plan. Report on Form 10-Q for the
quarter ended September 30, 1993.
10.48.1** First Amendment to the Public Service Company of 10.48.1 to the Company's 1-6986
New Mexico OBRA '93 Retirement Plan, as amended Quarterly Report on Form 10-Q
effective December 7, 1998 for the quarter ended March 31,
1999.
E-12
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.49** Employment Contract By and Between 10.49 to Annual Report of the 1-6986
Public Service Company of New Mexico and Roger Registrant on Form 10-K for
J. Flynn. fiscal year ended December 31,
1994.
10.50** Public Service Company of New Mexico 10.50 to Annual Report of the 1-6986
Section 415 Plan. Registrant on Form 10-K for
fiscal year ended December 31,
1993.
10.51.2** First Restated and Amended Executive Retention 10.51.2 to the Company's 1-6986
Plan, as amended effective December 7, 1998 Quarterly Report on Form 10-Q
for the quarter ended March 31,
1999.
10.53 January 12, 1994 Stipulation. 10.53 to Annual Report of the 1-6986
Registrant on
Form 10-K for
fiscal year
ended December
31, 1993.
10.54.1** Health Care and Retirement Benefit 10.54.1 to the Company's 1-6986
Agreement By and Between the Public Quarterly Report on Form 10-Q
Service Company of New Mexico and for the quarter ended March 31,
John T. Ackerman dated February 1, 1994. 1994.
10.56.1 Amended and Restated Receivables Purchase 10.56.1 to the Company's 1-6986
Agreement dated May 20, 1996, between Public Quarterly Report on
Service Company of New Mexico, Citibank and Form 10-Q for the
Citicorp North America, Inc. and Amended quarter ended June 30,
Restated Collection Agent Agreement dated 1996.
May 20, 1996, between Public Service Company
of New Mexico, Corporate Receivables
Corporation and Citibank, N.A.
10.59* Amended and Restated Lease dated as of 10.59 to Annual Report of the 1-6986
September 1, 1993, between The First Registrant on Form 10-K for
National Bank of Boston, Lessor, and fiscal year ended December
31, the Company, Lessee (EIP Lease). 1993.
10.61 Participation Agreement dated as of June 10.61 to Annual Report of the 1-6986
30, 1983 among Security Trust Company, Registrant on Form 10-K for
as Trustee, the Company, Tucson Electric fiscal year ended December 31,
Power Company and certain financial 1993.
institutions relating to the San Juan Coal
Trust (refiled).
10.62 Agreement of the Company pursuant to 10.62 to Annual Report of the 1-6986
Item 601(b)(4)(iii) of Regulation S-K Registrant on Form 10-K for
(refiled). fiscal year ended December 31,
1993.
E-13
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.64** Results Pay 10.64 to the Company's Quarterly 1-6986
Report on Form 10-Q for the
quarter ended March 31, 1995.
10.65 Agreement for Contract Operation and 10.64 to the Company's Quarterly 1-6986
Maintenance of the City of Santa Fe Report on Form 10-Q for the
Water Supply Utility System, dated quarter ended June 30, 1995.
July 3, 1995.
10.67 New Mexico Public Service Commission 10.67 to Annual Report of the 1-6986
Order dated July 30, 1987, and Exhibit I Registrant on Form 10-K for
thereto, in NMPUC Case No. 2004, fiscal year ended December 31,
regarding the PVNGS decommissioning 1997.
trust fund (refiled).
10.68 Master Decommissioning Trust Agreement 10.68 to the Company's Quarterly 1-6986
for Palo Verde Nuclear Generating Station Report on Form 10-Q for the
dated March 15, 1996, between Public quarter ended March 31, 1996.
Service Company of New Mexico and
Mellon Bank, N.A.
10.68.1 Amendment Number One to the Master 10.68.1 to Annual Report of the 1-6986
Decommissioning Trust Agreement for Registrant on Form 10-K for
Palo Verde Nuclear Generating Station fiscal year ended December 31,
dated January 27, 1997, between Public 1997.
Service Company of New Mexico and
Mellon Bank, N.A.
10.69* Refunding Agreement No. 3 dated as 10.69 to the Company's 1-6986
of September 27, 1996 between Public Quarterly Report on Form
Service Company of New Mexico, The 10-Q for the quarter ended
Owner Participant named therein, September 30, 1996.
State Street Bank and Trust Company,
as Owner Trustee, The Chase Manhattan,
Bank, as Indenture Trustee, and First PV
Funding Corporation.
10.72 Revolving Credit Agreement dated as of 10.72 to the Company's Quarterly 1-6986
March 11, 1998, among the Company, Report on Form 10-Q for the
the Chase Manhattan Bank, Citibank, quarter ended March 31, 1998.
N.A., Morgan Guaranty Trust Company
of New York, and Chase Securities, Inc.,
and the Initial Lenders Named Therein.
E-14
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.73 Refunding Agreement No. 8A, dated as 10.73 to the Company's Quarterly 1-6986
of December 23, 1997, among the Report on Form 10-Q for the
Company, the Owner Participant Named quarter ended March 31, 1998.
Therein, State Street Bank and Trust
Company, as Owner Trustee, The Chase
Manhattan Bank, as Indenture Trustee,
and First PV Funding Corporation.
10.74** Third Restated and Amended Public 10.74 to the Company's Quarterly 1-6986
Service Company of New Mexico Report on Form 10-Q for the
Performance Stock Plan. quarter ended March 31, 1998.
10.75** Executive Savings Plan 10.75 to the Company's Quarterly
Report on Form 10-Q for the
quarter ended June 30, 1998.
10.76 PVNGS Capital Trust--Variable Rate 10.76 to the Company's Quarterly 1-6986
Trust Notes--PVNGS Note Agreement Report on Form 10-Q for the
dated as of July 31, 1998. quarter ended September 30, 1998.
10.77 San Juan Project Participation Agreement dated 10.77 to the Company's Quarterly 1-6986
as of October 27, 1999, among Public Service Report on Form 10-Q for the
Company of New Mexico, Tucson Electric Power quarter ended September 30, 1999.
Company, The City of Farmington, New Mexico,
M-S-R Public Power Agency, The Incorporated
County of Los Alamos, New Mexico, Southern
California Public Power Authority, City of
Anaheim, Utah Associated Municipal Power
System and Tri-State Generation and
Transmission Association, Inc.
10.78 Stipulation in the matter of the Commission's 10.78 to the Company's Quarterly 1-6986
investigation of the rates for electric service Report on Form 10-Q for the
of Public Service Company of New Mexico, Rate quarter ended September 30, 1999.
Case No. 2761, dated May 21, 1999
10.78.1 Stipulation in the matter of the Commission's 10.78.1 to the Company's 1-6986
investigation of the rates for electric service Quarterly Report on Form
of Public Service Company of New Mexico, 10-Q the quarter ended
Rate for Case No. 2761, dated May 27, 1999 September 30, 1999.
E-15
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
10.79 Asset Sale Agreement between Tri-State 10.79 to the Company's Quarterly 1-6986
Generation and Transmission Association, Inc., Report on Form 10-Q for the
a Colorado Cooperative Association and Public quarter ended September 30, 1999.
Service Company of New Mexico, a New Mexico
Corporation, dated September 9, 1999
Additional Exhibits
21 Certain subsidiaries of the registrant. 22 to Annual Report of the 1-6986
Registrant on
Form 10-K for
fiscal year
ended December
31, 1992.
99.2* Participation Agreement dated as of 99.2 to Annual Report of the 1-6986
December 16, 1985, among the Owner Registrant on Form 10-K for
Participant named therein, First PV fiscal year ended December 31,
Funding Corporation. The First National 1995.
Bank of Boston, in its individual capacity
and as Owner Trustee (under a Trust
Agreement dated as of December 16, 1985
with the Owner Participant), Chemical
Bank, in its individual capacity and as
Indenture Trustee (under a Trust
Indenture, Mortgage, Security Agreement
and Assignment of Rents dated as of
December 16, 1985 with the Owner
Trustee), and Public Service Company of
New Mexico, including Appendix A
definitions together with Amendment No.
1 dated July 15, 1986 and Amendment No.
2 dated November 18, 1986 (refiled).
99.3 Trust Indenture, Mortgage, Security 99.3 to the Company's Quarterly 1-6986
Agreement and Assignment of Rents Report on Form 10-Q for the
dated as of December 16, 1985, between quarter ended March 31, 1996.
the First National Bank of Boston, as
Owner Trustee, and Chemical Bank, as
Indenture Trustee together with
Supplemental Indentures Nos. 1 and 2
(refiled).
99.3.3 Supplemental Indenture No. 3 dated as 99.3.3 to the Company's 1-6986
of March 8, 1995, to Trust Indenture Quarterly Report on Form 10-Q
Mortgage, Security Agreement and for the quarter ended March 31,
Assignment of Rents between The First 1995.
National Bank of Boston and Chemical
Bank dated as of December 16, 1985.
E-16
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
99.4* Assignment, Assumption and Further 99.4 to Annual Report of the 1-6986
Agreement dated as of December 16, Registrant on Form 10-K for
1985, between Public Service Company fiscal year ended December
of New Mexico and The First National 31, 1995.
Bank of Boston, as Owner Trustee (refiled).
99.5 Participation Agreement dated as of July 99.5 to Annual Report of the 1-6986
31, 1986, among the Owner Participant named Registrant on Form 10-K for
herein, First PV Funding Corporation, The fiscal year ended December 31,
First National Bank of Boston, in its 1996.
individual capacity and as Owner Trustee
(under a Trust Agreement dated as of July 31,
1986, with the Owner Participant), Chemical
Bank, in its individual capacity and as
Indenture Trustee (under a Trust Indenture,
Mortgage, Security Agreement and Assignment of
Rents dated as of July 31, 1986, with the
Owner Trustee), and Public Service Company of
New Mexico, including Appendix A definitions
together with Amendment No. 1 thereto
(refiled).
99.6 Trust Indenture, Mortgage, Security 99.6 to Annual Report of the 1-6986
Agreement and Assignment of Rents Registrant on Form 10-K for
dated as of July 31, 1986, between The fiscal year ended December
First National Bank of Boston, as Owner 31, 1996.
Trustee, and Chemical Bank, as Indenture
Trustee together with Supplemental Indenture
No. 1 thereto (refiled).
99.7 Assignment, Assumption, and Further 99.7 to Annual Report of the 1-6986
Agreement dated as of July 31, 1986, Registrant on Form 10-K for
between Public Service Company of fiscal year ended December 31,
New Mexico and The First National Bank 1996.
of Boston, as Owner Trustee (refiled).
E-17
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
99.8 Participation Agreement dated as of 99.8 to the Company's Quarterly 1-6986
August 12, 1986, among the Owner Report on Form 10-Q for the
Participant named therein, First PV quarter ended March 31, 1997.
Funding Corporation. The First National
Bank of Boston, in its individual capacity and
as Owner Trustee (under a Trust Agreement
dated as of August 12, 1986, with the Owner
Participant), Chemical Bank, in its individual
capacity and as Indenture Trustee (under a
Trust Indenture, Mortgage, Security Agreement
and Assignment of Rents dated as of August 12,
1986, with the Owner Trustee), and Public
Service Company of New Mexico, including
Appendix A definitions (refiled).
99.8.1* Amendment No. 1 dated as of November 99.8.1 to the Company's 1-6986
18, 1986, to Participation Agreement Quarterly Report on Form 10-Q
dated as of August 12, 1986 (refiled). for the quarter ended March 31,
1997.
99.9* Trust Indenture, Mortgage, Security 99.9 to Annual Report of the 1-6986
Agreement and Assignment of Rents Registrant on Form 10-K for
dated as of August 12, 1986, between the fiscal year ended
First National Bank of Boston, as Owner December 31,1996.
Trustee, and Chemical Bank, as Indenture
Trustee together with Supplemental Indenture
No. 1 thereto (refiled).
99.9.2 Supplemental Indenture No. 2 dated as 99.9.1 to the Company's 1-6986
of March 8, 1995, to Trust Indenture, Quarterly Report on Form 10-Q
Mortgage, Security Agreement and for the quarter ended March 31,
Assignment of Rents between The First 1995.
National Bank of Boston and Chemical
Bank dated as of August 12, 1986.
99.10* Assignment, Assumption, and Further 99.10 to the Company's Quarterly 1-6986
Agreement dated as of August 12, 1986, Report on Form 10-Q for the
between Public Service Company of New quarter ended March 31, 1997.
Mexico and The First National Bank of
Boston, as Owner Trustee (refiled).
E-18
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
99.11* Participation Agreement dated as of 99.1 to the Company's Quarterly 1-6986
December 15, 1986, among the Owner Report on Form 10-Q for the
Participant named therein, First PV quarter ended March 31, 1997.
Funding Corporation, The First National Bank
of Boston, in its individual capacity and as
Owner Trustee (under a Trust Agreement dated
as of December 15, 1986, with the Owner
Participant), Chemical Bank, in its individual
capacity and as Indenture Trustee (under a
Trust Indenture, Mortgage, Security Agreement
and Assignment of Rents dated as of December
15, 1986, with the Owner Trustee), and Public
Service Company of New Mexico, including
Appendix A definitions (Unit 1 Transaction)
(refiled).
99.12 Trust Indenture, Mortgage, Security 99.12 to the Company's Quarterly 1-6986
Agreement and Assignment of Rents Report on Form 10-Q for the
dated as of December 15, 1986, between quarter ended March 31, 1997.
The First National Bank of Boston, as
Owner Trustee, and Chemical Bank, as
Indenture Trustee (Unit 1 Transaction)
(refiled).
99.13 Assignment, Assumption and Further 99.13 to the Company's 1-6986
Agreement dated as of December 15, Quarterly Report on Form
1986, between Public Service Company 10-Q for the quarter ended
of New Mexico and The First National March 31, 1997.
Bank of Boston, as Owner Trustee
(Unit 1 Transaction) (refiled).
99.14 Participation Agreement dated as of 99.14 to the Company's 1-6986
December 15, 1986, among the Owner Quarterly Report on Form
Participant named therein, First PV 10-Q for the quarter ended
Funding Corporation, The First National March 31, 1997.
Bank of Boston, in its individual capacity and
as Owner Trustee (under a Trust Agreement
dated as of December 15, 1986, with the Owner
Participant), Chemical Bank, in its individual
capacity and as Indenture Trustee (under a
Trust Indenture, Mortgage, Security Agreement
and Assignment of Rents dated as of December
15, 1986, with the Owner Trustee), and Public
Service Company of New Mexico, including
Appendix A definitions (Unit 2 Transaction)
(refiled).
E-19
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
99.15 Trust Indenture, Mortgage, Security 99.15 to Annual Report of the 1-6986
Agreement and Assignment of Rents dated Registrant on Form 10-K
as of December 31, 1986, between the for fiscal year ended
First National Bank of Boston, as Owner December 31, 1996.
Trustee, and Chemical Bank, as Indenture
Trustee (Unit 2 Transaction) (refiled).
99.16 Assignment, Assumption, and Further 99.16 to the Company's Quarterly 1-6986
Agreement dated as of December 15, Report on Form 10-Q for the
1986, between Public Service Company quarter ended March 31, 1997.
of New Mexico and The First National
Bank of Boston, as Owner Trustee
(Unit 2 Transaction) (refiled).
99.17* Waiver letter with respect to "Deemed 99.17 to Annual Report of the 1-6986
Loss Event" dated as of August 18, 1986, Registrant on Form 10-K
between the Owner Participant named for fiscal year ended December
therein, and Public Service Company of 31, 1996.
New Mexico (refiled).
99.18* Waiver letter with respect to Deemed 99.18 to Annual Report of the 1-6986
Loss Event" dated as of August 18, 1986, Registrant on Form 10-K
for between the Owner Participant named for fiscal year ended December
therein, and Public Service Company of 31, 1996.
New Mexico (refiled).
99.19 Agreement No. 13904 (Option and 99.19 to Annual Report of the 1-6986
Purchase of Effluent), dated April 23, Registrant on Form 10-K for
1973, among Arizona Public Service fiscal year ended December 31,
Company, Salt River Project Agricultural 1996.
Improvement and Power District, the
Cities of Phoenix, Glendale, Mesa,
Scottsdale, and Tempe, and the Town of
Youngtown (refiled).
99.20 Agreement for the Sale and Purchase of 99.20 to Annual Report of the 1-6986
Wastewater Effluent, dated June 12, 1981, Registrant on Form 10-K
Among Arizona Public Service Company, for fiscal year ended
Salt River Project Agricultural Improvement December 31, 1996.
and Power District and the City of Tolleson,
as amended (refiled).
99.21* 1996 Supplemental Indenture dated as of 99.21 to the Company's Quarterly 1-6986
September 27, 1996 to Trust Indenture, Report on Form 10-Q for the
Mortgage, Security Agreement and quarter ended September 30, 1996.
Assignment of Rents dated as of December
16, 1985 between State Street Bank and
Trust Company, as Owner Trustee, and
The Chase Manhattan Bank, as Indenture
Trustee.
E-20
Exhibit No. Description of Exhibit Filed as Exhibit: File No:
- ----------- ---------------------- ----------------- --------
99.22 1997 Supplemental Indenture, dated as of 99.22 to the Company's Quarterly 1-6986
December 23, 1997, to Trust Indenture, Report on Form 10-Q for the
Mortgage, Security Agreement and quarter ended March 30, 1998.
Assignment of Rents, dated as of August
12, 1986, between State Street Bank and
Trust, as Owner Trustee, and The Chase
Manhattan Bank, as Indenture Trustee.
- -----------
* One or more additional documents, substantially identical in all material
respects to this exhibit, have been entered into, relating to one or more
additional sale and leaseback transactions. Although such additional
documents may differ in other respects (such as dollar amounts and
percentages), there are no material details in which such additional
documents differ from this exhibit.
** Designates each management contract or compensatory plan or arrangement
required to be identified pursuant to paragraph 3 of Item 14(a) of
Form 10 -K.
(b) Reports on Form 8-K:
During the quarter ended December 31, 1999 and during the period
beginning January 1, 2000 and ending March 8, 2000, the Company filed, on the
date indicated, the following report on Form 8-K.
Dated: Filed: Relating to:
------ ------ ------------
November 18, 1999 November 17, 1999 The Company Seeks to Form Holding Company
December 8, 1999 December 7, 1999 The Company Announces $20 Million Common Stock
Repurchase and Quarterly Dividend
January 26, 2000 January 27, 2000 The Company Names New President
January 27, 2000 January 27, 2000 The Company Reports 1999 Earnings of $2.01 Per Share
February 10, 2000 February 17, 2000 The Company's wholly-owned subsidiary, Avistar
Invests in Internet Energy Exchange
February 11, 2000 February 17, 2000 The Company Names New Senior Vice President
February 22, 2000 March 7, 2000 The Company Subsidiary Announces Technology
Partnership with Sandia National Labs
February 23, 2000 March 7, 2000 The Company Picks Manzano for New Holding Company
E-21
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized.
PUBLIC SERVICE COMPANY OF NEW MEXICO
(Registrant)
Date: March 9, 2000 By /s/ B. F. Montoya
-------------------------------
B. F. Montoya
Chairman, President and
Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934,
this report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
Signature Capacity Date
--------- -------- ----
/s/ B. F. MONTOYA Principal Executive Officer and March 9, 2000
- ---------------------------------------------- Chairman of the Board
B. F. MONTOYA
Chairman, President and
Chief Executive Officer
/s/ M. H. MAERKI Principal Financial Officer March 9, 2000
- ----------------------------------------------
M. H. Maerki
Senior Vice President and
Chief Financial Officer
/s/ J. R. LOYACK Principal Accounting Officer March 9, 2000
- ----------------------------------------------
J. R. Loyack
Vice President, Corporate Controller
and Chief Accounting Officer
/s/ J. T. ACKERMAN Director March 9, 2000
- ----------------------------------------------
J. T. Ackerman
/s/ R. G. ARMSTRONG Director March 9, 2000
- ----------------------------------------------
R. G. Armstrong
/s/ J. A. GODWIN Director March 9, 2000
- ----------------------------------------------
J. A. Godwin
/s/ L. H. LATTMAN Director March 9, 2000
- ----------------------------------------------
L. H. Lattman
/s/ M. LUJAN JR. Director March 9, 2000
- ----------------------------------------------
M. Lujan Jr.
/s/ R. U. ORTIZ Director March 9, 2000
- ----------------------------------------------
R. U. Ortiz
/s/ R. M. PRICE Director March 9, 2000
- ----------------------------------------------
R. M. Price
/s/ P. F. ROTH Director March 9, 2000
- ----------------------------------------------
P. F. Roth
E-22